Sample records for ao gas natural

Naturalgas is a naturally occurring mixture of simple hydrocarbons and nonhydrocarbons that exists as a gas at ordinary pressures and temperatures. In the raw state, as produced from the earth, naturalgas consists principally of methane (CH4) and ethane (C2H4), with fractional amounts of propane (C3H8), butane (C4H10), and other hydrocarbons, pentane (C5H12) and heavier. Occasionally, small traces of light aromatic hydrocarbons such as benzene and toluene may also be present.

The NaturalGas Annual provides information on the supply and disposition of naturalgas to a wide audience including industry, consumers, Federal and State agencies, and educational institutions. The 1994 data are presented in a sequence that follows naturalgas (including supplemental supplies) from its production to its end use. This is followed by tables summarizing naturalgas supply and disposition from 1990 to 1994 for each Census Division and each State. Annual historical data are shown at the national level.

The NaturalGas Annual provides information on the supply and disposition of naturalgas to a wide audience including industry, consumers, Federal and State agencies, and educational institutions. The 1995 data are presented in a sequence that follows naturalgas (including supplemental supplies) from its production to its end use. This is followed by tables summarizing naturalgas supply and disposition from 1991 to 1995 for each Census Division and each State. Annual historical data are shown at the national level.

This examines the role of gas in the world energy supply/demand. Special attention is paid to Western Europe, the Soviet Union, and the naturalgas exporting countries. Forecasts of global energy demand until 2000 and data on Western Europe's proven naturalgas reserves as per January 1982 are provided.

This is the final report of a two-year, Laboratory-Directed Research and Development (LDRD) project at the Los Alamos National Laboratory (LANL). This project sought to develop a natural-gas-powered natural-gas liquefier that has absolutely no moving parts and requires no electrical power. It should have high efficiency, remarkable reliability, and low cost. The thermoacoustic natural-gas liquefier (TANGL) is based on our recent invention of the first no-moving-parts cryogenic refrigerator. In short, our invention uses acoustic phenomena to produce refrigeration from heat, with no moving parts. The required apparatus comprises nothing more than heat exchangers and pipes, made of common materials, without exacting tolerances. Its initial experimental success in a small size lead us to propose a more ambitious application: large-energy liquefaction of naturalgas, using combustion of naturalgas as the energy source. TANGL was designed to be maintenance-free, inexpensive, portable, and environmentally benign.

RAMSGAS, the Research and Development Analysis Modeling System World NaturalGas Model, was developed to support planning of unconventional gaseoues fuels research and development. The model is a scenario analysis tool that can simulate the penetration of unconventional gas into world markets for oil and gas. Given a set of parameter values, the model estimates the naturalgas supply and demand for the world for the period from 1980 to 2030. RAMSGAS is based onmore » a supply/demand framwork and also accounts for the non-renewable nature of gas resources. The model has three fundamental components: a demand module, a wellhead production cost module, and a supply/demand interface module. The demand for gas is a product of total demand for oil and gas in each of 9 demand regions and the gas share. Demand for oil and gas is forecast from the base year of 1980 through 2030 for each demand region, based on energy growth rates and price-induced conservation. For each of 11 conventional and 19 unconventional gas supply regions, wellhead production costs are calculated. To these are added transportation and distribution costs estimates associated with moving gas from the supply region to each of the demand regions and any economic rents. Based on a weighted average of these costs and the world price of oil, fuel shares for gas and oil are computed for each demand region. The gas demand is the gas fuel share multiplied by the total demand for oil plus gas. This demand is then met from the available supply regions in inverse proportion to the cost of gas from each region. The user has almost complete control over the cost estimates for each unconventional gas source in each year and thus can compare contributions from unconventional resources under different cost/price/demand scenarios.« less

This report presents data on the supply and disposition of naturalgas in the USA during July 1982, as well as data on production, storage, imports, exports, and consumption. Selected data are also presented on the activities of the major interstate pipeline companies. Volumes of naturalgas in storage continue to run slightly ahead of year-ago levels, especially for interstate operators. Weighted average prices received for gas sold by major interstate pipeline companies during July of 19982 ranged from a low of $2.61 per thousand cubic feet (Mcf) for Kansas-Nebraska to a high of $7.09 per Mcf for Pacific Gas. These variations are attributable to the sources of supply available to the various pipeline companies and the market structures of each. September 1982 applications for determination of a maximum lawful price under the NaturalGas Policy Act (NGPA) increased slightly for new gas (Section 102) and decreased significantly for high-cost gas (Section 107) when compared to August. Naturalgas ceiling prices prescribed by the NGPA continued to move upward through the application of prescribed monthly inflation adjustments. In the 3-year period from November 1979 through November 1982, the price ceiling for new gas, for example, increased from $2.314 to $3.249 per million (MM) Btu's. The highest ceiling price permitted under the NGPA is naturalgas produced from tight formations set for November 1982 at $5.396 per MMBtu. Market naturalgas production during September of 1982 was 1444 billion cubic feet (Bcf) compared to the September 1981 level of 1578 Bcf. Consumption during the same period also declined from 1266 Bcf to 1176 Bcf.

This document highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Data presented include volume and price, production, consumption, underground storage, and interstate pipeline activities.

After the disaster of Staten Island in 1973 where 40 people were killed repairing a liquid naturalgas storage tank, the New York Fire Commissioner requested NASA's help in drawing up a comprehensive plan to cover the design, construction, and operation of liquid naturalgas facilities. Two programs are underway. The first transfers comprehensive risk management techniques and procedures which take the form of an instruction document that includes determining liquid-gas risks through engineering analysis and tests, controlling these risks by setting up redundant fail safe techniques, and establishing criteria calling for decisions that eliminate or accept certain risks. The second program prepares a liquid gas safety manual (the first of its kind).

Despite recent optimism about the outlook for the future supply of domestic conventional naturalgas, the Congressional Office of Technology Assessment (OTA) finds insufficient evidence to clearly justify either an optimistic or a pessimistic view. In a technical memorandum entitled “U.S. NaturalGas Availability: Conventional Gas Supply Through the Year 2000,” released recently by Rep. Philip R. Sharp (D-Ind,), chairman of the Subcommittee on Fossil and Synthetic Fuels of the Committee on Energy and Commerce, OTA concluded that substantial technical uncertainties prevented a reliable estimation of the likely naturalgas production rates for later in this century. Even ignoring the potential for significant changes in gas prices and technology, OTA estimated that conventional gas production by the lower 48 states in the year 2000 could range from 9 to 19 trillion cubic feet (TCF) (0.25 to 0.53 trillion cubic meters), compared to 1982 production of 17.5 TCF. Similarly, production in the year 1990 could range from 13 to 20 TCF.

With almost as many vital economic interests as there were attendees, two naturalgas international conferences were held in North America during September and October, to share experience and forecasts. On September 26, the Canadian Energy Research Institute (CERI) and the Calgary Chamber of Commerce sponsored the International Gas Markets Conference and drew 400 persons. And on October 5-6, at the University of Colorado at Boulder, USA, the International Research Center for Energy and Economic Development (ICEED) held its Tenth International Energy Conference on Economic and Political Issues of NaturalGas in International Trade, drawing some 200 experts. The latter seminar was preceded by a two-day seminar on Asian Energy Supplies and Requirements, which also featured naturalgas in many of its presentations. To provide an overview of some of these pressing questions, Energy Detente reports on these two comprehensive seminars on naturalgas. This issue also presents the fuel price/tax series and the principal industrial fuel prices for the Eastern Hemisphere for November 1983.

An improved process for converting all naturalgas hydrocarbon components with carbon numbers of 1 to 4 into liquid hydrocarbons with carbon numbers equal to or greater than 5, and into a hydrogen-rich gaseous by-product which is described comprising the following steps: A. Splitting the naturalgas feed into a rich gas stream comprising C/sub 2/, C/sub 3/ and C/sub 4/ hydrocarbons and a lean gas stream comprising C/sub 1/ and C/sub 2/ hydrocarbons; B. Catalytically converting the rich gas stream in a catalytic bed reactor in which the gas-suspended solid phase is a catalyst maintained at a temperature not exceeding 600/sup 0/C.; Separating the gaseous effluent from the catalytic bed reactor into (1) a hydrogen-rich stream; (2) a lean gas stream comprising hydrogen, C/sub 1/ and C/sub 2/ hydrocarbons, (3) a rich gas stream comprising C/sub 2/ and C/sub 3/ and C/sub 4/ hydrocarbons and (4) a liquid product stream comprising C/sub 5/ + hydrocarbons; D. Pre-heating all lean gas streams, including recycle, in a furnace; E. Transferring the catalyst into a short residence time reactor; F. Reacting an ionized plasma derived from the hydrogen stream with the pre-heated lean gas stream; G. Separating the gas-solid stream resulting from the reaction into a spent catalyst phase stream and a gaseous effluent stream; H. Separating the gaseous effluent stream from the disengagement means into four streams; I. Regenerating the spent catalyst stream in a regenerator by combustion of the carbon build-up on the spent catalyst in an oxidizing gas stream; J. Transferring the regenerated catalyst back into the catalytic bed reactor and into the short residence time reactor; K. Recycling all rich gas streams obtained in steps C and H back to the catalytic bed reactor; L. Recycling the lean gas stream obtained in step H back to the pre-heating furnace of step D.

This article promotes naturalgas use as a means to cut US dependence on imported oil by some 28 percent over the next ten years, while improving energy efficiency and solving a portion of the global warming and acid rain problems. Topics of discussion include fuel substitution, the Clean Air Act, naturalgas capacity and distribution, and naturalgas exploration.

Provides information on the supply and disposition of naturalgas in the United States. Production, transmission, storage, deliveries, and price data are published by state for the current year. Summary data are presented for each state for the previous 5 years.

This report presents estimates of proved reserves of crude oil, naturalgas, and naturalgas liquids as of December 31, 1989, and production volumes for the year 1989 for the total United States and for selected states and state sub-divisions. Estimates are presented for the following four categories of naturalgas: total gas (wet after lease separation), its two major components (nonassociated and associated-dissolved gas), and total dry gas (wet gas adjusted for the removal of liquids at naturalgas processing plants). In addition, two components of naturalgas liquids, lease condensate and naturalgas plant liquids, have their reserves and production reported separately. Also included is information on indicated additional crude oil reserves and crude oil, naturalgas, and lease condensate reserves in nonproducing reservoirs. 28 refs., 9 figs., 15 tabs.

Cryenco and Los Alamos are collaborating to develop a natural-gas-powered natural-gas liquefier that will have no moving parts and require no electrical power. It will have useful efficiency, remarkable reliability, and low cost. The liquefaction of naturalgas, which occurs at only 115 Kelvin at atmospheric pressure, has previously required rather sophisticated refrigeration machinery. The 1990 invention of the thermoacoustically driven orifice pulse-tube refrigerator (TA-DOPTR) provides cryogenic refrigeration with no moving parts for the first time. In short, this invention uses acoustic phenomena to produce refrigeration from heat. The required apparatus consists of nothing more than helium-filled heat exchangers and pipes, made of common materials, without exacting tolerances. In the Cryenco-Los Alamos collaboration, the authors are developing a version of this invention suitable for use in the natural-gas industry. The project is known as acoustic liquefier for short. The present program plans call for a two-phase development. Phase 1, with capacity of 500 gallon per day (i.e., approximately 40,000 scfd, requiring a refrigeration power of about 7 kW), is large enough to illuminate all the issues of large-scale acoustic liquefaction without undue cost, and to demonstrate the liquefaction of 60--70% of input gas, while burning 30--40%. Phase 2 will target versions of approximately 10{sup 6} scfd = 10,000 gallon per day capacity. In parallel with both, they continue fundamental research on the technology, directed toward increased efficiency, to build scientific foundations and a patent portfolio for future acoustic liquefiers.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. There are two feature articles in this issue: Naturalgas 1998: Issues and trends, Executive summary; and Special report: Naturalgas 1998: A preliminary summary. 6 figs., 28 tabs.

This assessment of the naturalgas sector in Iran, with a focus on Iran’s naturalgas exports, was prepared pursuant to section 505 (a) of the Iran Threat Reduction and Syria Human Rights Act of 2012 (Public Law No: 112-158). As requested, it includes: (1) an assessment of exports of naturalgas from Iran; (2) an identification of the countries that purchase the most naturalgas from Iran; (3) an assessment of alternative supplies of naturalgas available to those countries; (4) an assessment of the impact a reduction in exports of naturalgas from Iran would have on global naturalgas supplies and the price of naturalgas, especially in countries identified under number (2); and (5) such other information as the Administrator considers appropriate.

The NaturalGas Monthly (NGM) is prepared in the Data Operations Branch of the Reserves and NaturalGas Division, Office of Oil and Gas, Energy Information Administration (EIA), US Department of Energy (DOE). The NGM highhghts activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. The feature article this month is entitled ``Intricate puzzle of oil and gas reserves growth.`` A special report is included on revisions to monthly naturalgas data. 6 figs., 24 tabs.

The NaturalGas Monthly (NGM) is prepared in the Data Operations Branch of the Reserves and NaturalGas Division, Office of Oil and Gas, Energy Information Administration (EIA), U.S. Department of Energy (DOE). The NGM highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NaturalGas Monthly (NGM) is prepared in the Data Operations Branch of the Reserves and NaturalGas Division, Office of Oil and Gas, Energy Information Administration (EIA), US Department of Energy (DOE). The NGM highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NaturalGas Monthly (NGM) is prepared in the Data Operations Branch of the Reserves and NaturalGas Division, Office of Oil and Gas, Energy Information Administration (EIA), US Department of energy (DOE). The NGM highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

World marketed production of naturalgas in 1978 totaled 51.749 trillion CF (up from 50.1 TCF in 1977); this 3.3% increase, however, was slightly lower than 1977's 3.7% rise. US production, which fell 0.3% dropped to 38.6% of the world total, while the USSR share (13.137 TCF) accounted for 25.4% (for a growth rate of 7.5%). Of the world gross production of 62.032 TCF, 69.7% came from gas wells; the remainder was associated with oil. Thirty-one percent of the 10.282 TCF difference between gross and marketed gas production was used for oil reservoir repressuring, while the balance (7.094 TCF) was vented and flared. Internationally traded gas movements rose to 11.6% of production. The Netherlands, the USSR, and Canada accounted for 30.6%, 20.1% and 14.7%, respectively, of total 1978 exports. At 0.956 TCF, LNG shipments accounted for 15.9% of world trade, a 35.2% higher share than in 1977; most of this growth was due to increased Indonesia-to-Japan volumes.

The NaturalGas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. 6 figs., 31 tabs.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. Articles are included which are designed to assist readers in using and interpreting naturalgas information.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground state data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. 6 figs., 24 tabs.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. 6 figs., 25 tabs.

The NaturalGas Monthly NGM highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. 6 figs., 25 tabs.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time the NGM features articles designed to assist readers in using and interpreting naturalgas information. 6 figs., 27 tabs.

In collaboration with Cryenco Inc. and NIST-Boulder, we intend to develop a naturalgas-powered natural-gas liquefier which has absolutely no moving parts and requires no electrical power. It will have high efficiency, remarkable reliability, and low cost. Progress on the liquefier to be constructed at Cryenco continues satisfactorily. The thermoacoustic driver is still ahead of the pulse tube refrigerator, because of NIST`s schedule. We completed the thermoacoustics design in the fall of 1994, with Los Alamos providing physics input and checks of all aspects, and Cryenco providing engineering to ASME code, drafting, etc. Completion of this design represents a significant amount of work, especially in view of the many unexpected problems encountered. Meanwhile, Cryenco and NIST have almost completed the design of the pulse tube refrigerator. At Los Alamos, we have assembled a half-size scale model of the thermoacoustic portion of the 500 gal/day TANGL. This scale model will enable easy experimentation in harmonic suppression techniques, new stack geometries, new heat-exchanger geometries, resonator coiling, and other areas. As of March 1995, the scale model is complete and we are performing routine debugging tests and modifications.

The naturalgas monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. The feature article for this month is NaturalGas Industry Restructuring and EIA Data Collection.

The report highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NaturalGas Monthly features articles designed to assist readers in using and interpreting naturalgas information. The feature article this month is ``US naturalgas imports and exports-1995``. 6 figs., 24 tabs.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. This month`s feature article is on US NaturalGas Imports and Exports 1994.

The NaturalGas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. This month`s feature article focuses on preliminary highlights from the 1995 naturalgas industry. 7 figs., 25 tabs.

The (NGM) NaturalGas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. This month`s feature articles are: US Production of NaturalGas from Tight Reservoirs: and Expanding Rule of Underground Storage.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are present3ed each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. The feature article is entitled ``Naturalgas pipeline and system expansions.`` 6 figs., 27 tabs.

The NaturalGas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. The feature article in this issue is a special report, ``Comparison of NaturalGas Storage Estimates from the EIA and AGA.`` 6 figs., 26 tabs.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. The feature article this month is the executive summary from NaturalGas 1994: Issues and Trends. 6 figs., 31 tabs.

The NaturalGas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. The feature article this month is ``Restructuring energy industries: Lessons from naturalgas.`` 6 figs., 26 tabs.

The NaturalGas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. The article this month is entitled ``Recent Trends in NaturalGas Spot Prices.`` 6 figs., 27 tabs.

This issue of the NaturalGas Monthly presents the most recent estimates of naturalgas data from the Energy Information Administration (EIA). Estimates extend through April 1998 for many data series. The report highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, feature articles are presented designed to assist readers in using and interpreting naturalgas information. This issue contains the special report, ``NaturalGas 1997: A Preliminary Summary.`` This report provides information on naturalgas supply and disposition for the year 1997, based on monthly data through December from EIA surveys. 6 figs., 28 tabs.

The National Gas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

Chicago Bridge & Iron Company's tanks and associated piping are parts of system for transferring liquefied naturalgas from ship to shore and storing it. LNG is a "cryogenic" fluid meaning that it must be contained and transferred at very low temperatures, about 260 degrees below Fahrenheit. Before the LNG can be pumped from the ship to the storage tanks, the two foot diameter transfer pipes must be cooled in order to avoid difficulties associated with sharp differences of temperature between the supercold fluid and relatively warm pipes. Cooldown is accomplished by sending small steady flow of the cryogenic substance through the pipeline; the rate of flow must be precisely controlled or the transfer line will be subjected to undesirable thermal stress.

The NGM highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NGM highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information.

The NGM highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. The NGM also features articles designed to assist readers in using and interpreting naturalgas information.

The March 1998 edition of the NaturalGas Monthly highlights activities, events, and analyses associated with the naturalgas industry. Volume and price data are presented for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. This report also features an article on the correction of errors in the drilling activity estimates series, and in-depth drilling activity data. 6 figs., 28 tabs.

The NaturalGas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. A glossary of the terms used in this report is provided to assist readers in understanding the data presented in this publication. 6 figs., 30 tabs.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. The featured article for this month is on US coalbed methane production.

The main objective is to design and operate a laboratory apparatus for the catalytic reforming of naturalgas in order to provide data for a large-scale process. To accelerate the assembly and calibration of this equipment, a request has been made to the Lawrence Berkeley Laboratory for assistance, under the DOE's Industrial Visitor Exchange Program. Pr. Heinz Heinemann (Catalysis), Dr. John Apps (Geochemistry) and Dr. Robert Fulton (Mechanical Engineering) have expressed interest in supporting our request. Pr. Heinemann's recent results on the conversion of Petroleum Coke residues into CO2 and H2 mixtures using highly basic metal oxides catalysts, similar to ours, are very encouraging regarding the possibility of converting the Coke residue on our catalyst into Syngas in the Regenerator/riser, as proposed. To minimize Coke formation in the vapor phase, by the Plasmapyrolytic Methane Conversion reactions, the experimental data of H. Drost et al. (Ref. 12) have been reviewed. Work is underway to design equipment for the safe and non-polluting disposal of the two gaseous product streams of the flow loop. 2 refs.

The NaturalGas Monthly (NGM) is prepared in the Data Operations Branch of the Reserves and NaturalGas Division, Office of Oil and Gas, Energy Information Administration (EIA), US Department of Energy (DOE). The NGM highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. The data in this publication are collected on surveys conducted by the EIA to fulfill its responsibilities for gathering and reporting energy data. Some of the data are collected under the authority of the Federal Energy Regulatory Commission (FERC), an independent commission within the DOE, which has jurisdiction primarily in the regulation of electric utilities and the interstate naturalgas industry. Geographic coverage is the 50 States and the District of Columbia. 16 figs., 33 tabs.

... before you dig on your property. If you smell gas outdoors, move away from the area until you no longer smell the gas and call 911. Do not return ... it is safe to do so. If you smell gas indoors, get outside immediately, leaving doors open ...

The United States relies on naturalgas for one-quarter of its energy needs. In 2001 alone, the nation consumed 21.5 trillion cubic feet of naturalgas. A large portion of naturalgas pipeline capacity within the United States is directed from major production areas in Texas and Louisiana, Wyoming, and other states to markets in the western, eastern, and midwestern regions of the country. In the past 10 years, increasing levels of gas from Canada have also been brought into these markets (EIA 2007). The United States has several major naturalgas production basins and an extensive naturalgas pipeline network, with almost 95% of U.S. naturalgas imports coming from Canada. At present, the gas pipeline infrastructure is more developed between Canada and the United States than between Mexico and the United States. Gas flows from Canada to the United States through several major pipelines feeding U.S. markets in the Midwest, Northeast, Pacific Northwest, and California. Some key examples are the Alliance Pipeline, the Northern Border Pipeline, the Maritimes & Northeast Pipeline, the TransCanada Pipeline System, and Westcoast Energy pipelines. Major connections join Texas and northeastern Mexico, with additional connections to Arizona and between California and Baja California, Mexico (INGAA 2007). Of the naturalgas consumed in the United States, 85% is produced domestically. Figure 1.1-1 shows the complex North American naturalgas network. The pipeline transmission system--the 'interstate highway' for naturalgas--consists of 180,000 miles of high-strength steel pipe varying in diameter, normally between 30 and 36 inches in diameter. The primary function of the transmission pipeline company is to move huge amounts of naturalgas thousands of miles from producing regions to local naturalgas utility delivery points. These delivery points, called 'city gate stations', are usually owned by distribution companies, although some are owned by transmission companies

A system is described that is suitable for use in determining the location of leaks of gases having a background concentration. The system is a point-wise backscatter absorption gas measurement system that measures absorption and distance to each point of an image. The absorption measurement provides an indication of the total amount of a gas of interest, and the distance provides an estimate of the background concentration of gas. The distance is measured from the time-of-flight of laser pulse that is generated along with the absorption measurement light. The measurements are formated into an image of the presence of gas in excess of the background. Alternatively, an image of the scene is superimosed on the image of the gas to aid in locating leaks. By further modeling excess gas as a plume having a known concentration profile, the present system provides an estimate of the maximum concentration of the gas of interest.

This issue of the NaturalGas Monthly (NGM) presents the most recent estimates of naturalgas data from the Energy Information Administration. Estimates extend through February 1998 for many data series, and through November 1997 for most naturalgas prices. Highlights of the naturalgas data contained in this issue are: Preliminary estimates for January and February 1998 show that dry naturalgas production, net imports, and consumption are all within 1 percent of their levels in 1997. Warmer-than-normal weather in recent months has resulted in lower consumption of naturalgas by the residential sector and lower net withdrawals of gas from under round storage facilities compared with a year ago. This has resulted in an estimate of the amount of working gas in storage at the end of February 1998 that is 18 percent higher than in February 1997. The national average naturalgas wellhead price is estimated to be $3.05 per thousand cubic feet in November 1997, 7 percent higher than in October. The cumulative average wellhead price for January through November 1997 is estimated to be $2.42 per thousand cubic feet, 17 percent above that of the same period in 1996. This price increase is far less than 36-percent rise that occurred between 1995 and 1996. 6 figs., 26 tabs.

This special report provides an overview of the supply and disposition of naturalgas in 2004 and is intended as a supplement to the Energy Information Administration's (EIA) NaturalGas Annual 2004 (NGA). Unless otherwise stated, all data and figures in this report are based on summary statistics published in the NGA 2004.

This report highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. A glossary is included. 7 figs., 33 tabs.

This report highlights activities, events, and analyses of interest to public and private sector oganizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. 33 tabs.

Prepared by energy experts and educators to introduce middle school and high school students to naturalgas and its role in our society, this kit is designed to be incorporated into existing science and social studies curricula. The materials and activities focus on the origin, discovery, production, delivery, and use of naturalgas. The role of…

This document highlights activities, events, and analysis of interest to the public and private sector associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also included.

Significant events have transpired on the naturalgas hydrate research and development front since "Future Supply Potential of NaturalGas Hydrates" appeared in NaturalGas 1998 Issues and Trends and in the Potential Gas Committee's 1998 biennial report.

The NaturalGas Vehicle Coalition`s Measurement and Metering Task Group (MMTG) was established on July 1st, 1992 to develop suggested revisions to National Institute of Standards & Technology (NIST) Handbook 44-1992 (Specifications, Tolerances, and Other Technical Requirements for Weighing and Measuring Devices) and NIST Handbook 130-1991 (Uniform Laws & Regulations). Specifically, the suggested revisions will address the sale and measurement of compressed naturalgas when sold as a motor vehicle fuel. This paper briefly discusses the activities of the MMTG and its interaction with NIST. The paper also discusses the Institute of Gas Technology`s (IGT) support of the MMTG in the area of naturalgas composition, their impact on metering technology applicable to high pressure fueling stations as well as conversion factors for the establishment of ``gallon gasoline equivalent`` of naturalgas. The final portion of this paper discusses IGT`s meter research activities and its meter test facility.

This text analyzes the federal statutes and regulations that affect the pricing and allocation of crude oil, naturalgas, and naturalgas liquids. It does not cover refined products or imported crude oil except where necessary to place major decisions in historical context. Chapter 300 concerns naturalgas liquids. For historical rather than logical reasons, these are regulated as an offshoot of crude oil controls rather than as a by-product of naturalgas production. In December 1979, the Economic Regulatory Administration (ERA) deregulated butane and natural gasoline. However, it did not amend 10 CFR 212.161-212.173, and it did not deregulate propane or propane mixtures. Decontrol will be covered in the first update to this book. Chapters 400 to 468 concern naturalgas. Although a great deal of attention has been focused on the NaturalGas Policy Act (NGPA), there has been no satisfactory description of the extent to which the NaturalGas Act (NGA; passed in 1938 and amended by the Phillips decision in 1954) still applies. This is quite a problem, since the NGPA is written in vague terms that encourage producers to disregard the NGA. The problem is compounded by the Federal Power Commission's (FPC) approach to regulatory development, which has scattered crucial regulations throughout 18 CFR. All Federal Energy Regulatory Commission (FERC) naturalgas production regulations should be repealed, arranged into a systematic grouping, and reissued in a consolidated subpart of 18 CFR. Shortly after the publication of this text, the author will petition the FERC to commence a rulemaking proceeding to that effect. Chapters 480 to 498 will cover the use of naturalgas. These chapters will be issued in the first revision to this text as general summaries since the programs do not directly affect gas producers.

This report sunnnarizes the research by an Energy Modeling Forum working group on the evolution of the North American naturalgas markets between now and 2010. The group's findings are based partly on the results of a set of economic models of the naturalgas industry that were run for four scenarios representing significantly different conditions: two oil price scenarios (upper and lower), a smaller total US resource base (low US resource case), and increased potential gas demand for electric generation (high US demand case). Several issues, such as the direction of regulatory policy and the size of the gas resource base, were analyzed separately without the use of models.

This report summarizes die research by an Energy Modeling Forum working group on the evolution of the North American naturalgas markets between now and 2010. The group's findings are based partly on the results of a set of economic models of the naturalgas industry that were run for four scenarios representing significantly different conditions: two oil price scenarios (upper and lower), a smaller total US resource base (low US resource case), and increased potential gas demand for electric generation (high US demand case). Several issues, such as the direction of regulatory policy and the size of the gas resource base, were analyzed separately without the use of models.

The NaturalGas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. Explanatory notes supplement the information found in tables of the report. A description of the data collection surveys that support the NGM is provided. A glossary of the terms used in this report is also provided to assist readers in understanding the data presented in this publication.

Environmental and economic benefits could accrue from a safe, above-ground, natural-gas storage process allowing electric power plants to utilize naturalgas for peak load demands; numerous other applications of a gas storage process exist. A laboratory study conducted in 1999 to determine the feasibility of a gas-hydrates storage process looked promising. The subsequent scale-up of the process was designed to preserve important features of the laboratory apparatus: (1) symmetry of hydrate accumulation, (2) favorable surface area to volume ratio, (3) heat exchanger surfaces serving as hydrate adsorption surfaces, (4) refrigeration system to remove heat liberated from bulk hydrate formation, (5) rapid hydrate formation in a non-stirred system, (6) hydrate self-packing, and (7) heat-exchanger/adsorption plates serving dual purposes to add or extract energy for hydrate formation or decomposition. The hydrate formation/storage/decomposition Proof-of-Concept (POC) pressure vessel and supporting equipment were designed, constructed, and tested. This final report details the design of the scaled POC gas-hydrate storage process, some comments on its fabrication and installation, checkout of the equipment, procedures for conducting the experimental tests, and the test results. The design, construction, and installation of the equipment were on budget target, as was the tests that were subsequently conducted. The budget proposed was met. The primary goal of storing 5000-scf of naturalgas in the gas hydrates was exceeded in the final test, as 5289-scf of gas storage was achieved in 54.33 hours. After this 54.33-hour period, as pressure in the formation vessel declined, additional gas went into the hydrates until equilibrium pressure/temperature was reached, so that ultimately more than the 5289-scf storage was achieved. The time required to store the 5000-scf (48.1 hours of operating time) was longer than designed. The lower gas hydrate formation rate is attributed to a

This issue of the NaturalGas Monthly presents the most recent estimates of naturalgas data from the Energy Information Administration. Estimates extend through November for many data series, and through August for most naturalgas prices. Highlights of the most recent data estimates are: (1) Preliminary estimates of dry naturalgas production and total consumption available through November 1997 indicate that both series are on track to end the year at levels close to those of 1996. Cumulative dry production is one-half percent higher than in 1996 and consumption is one-half percent lower. (2) Naturalgas production is estimated to be 52.6 billion cubic feet per day in November 1997, the highest rate since March 1997. (3) After falling 8 percent in July 1997, the national average wellhead price rose 10 percent in August 1997, reaching an estimated $2.21 per thousand cubic feet. (4) Milder weather in November 1997 compared to November 1996 has resulted in significantly lower levels of residential consumption of naturalgas and net storage withdrawls than a year ago. The November 1997 estimates of residential consumption and net withdrawls are 9 and 20 percent lower, respectively, than in November 1996.

Work continued on Task No. 3. Particular attention was given to the back pressure control at the two gaseous effluent outlets and to the incineration of these effluents prior to their disposal. Temperature of the riser/regenerator and steam requirements were predicted from the gasification kinetics of coke and of coal char experimentally determined at atmospheric pressure, but at somewhat lower temperatures by H. Heinemann. The results of interactions of CH4 molecules with a Hydrogen Plasma in the adsorbed layer at the surface of refractory oxides were compared with those in the gas phase in order to select the optimum temperature range in the Cyclone reactor.

This issue of the NaturalGas Monthly contains estimates for March 1999 for many naturalgas data series at the national level. Estimates of national naturalgas prices are available through December 1998 for most series. Highlights of the data contained in this issue are listed below. Preliminary data indicate that the national average wellhead price for 1998 declined to 16% from the previous year ($1.96 compared to $2.32 per thousand cubic feet). At the end of March, the end of the 1998--1999 heating season, the level of working gas in underground naturalgas storage facilities is estimated to be 1,354 billion cubic feet, 169 billion cubic feet higher than at the end of March 1998. Gas consumption during the first 3 months of 1999 is estimated to have been 179 billion cubic feet higher than in the same period in 1998. Most of this increase (133 billion cubic feet) occurred in the residential sector due to the cooler temperatures in January and February compared to the same months last year. According to the National Weather Service, heating degree days in January 1999 were 15% greater than the previous year while February recorded a 5% increase.

The Small Business Innovation Research (SBIR) program was created in 1982 by Public Law 97-219 and reauthorized in 1992 until the year 2000 by Public Law 102-564. The purposes of the new law are to (1) expand and improve the SBIR program, 2) emphasize the program`s goal of increasing private sector commercialization of technology developed through Federal R&D, (3) increase small business participation in Federal R&D, and (4) improve the Federal Government`s dissemination of information concerning the SBIR program. DOE`s SBIR pro-ram has two features that are unique. In the 1995 DOE SBIR solicitation, the DOE Fossil Energy topics were: environmental technology for naturalgas, oil, and coal; advanced recovery of oil; naturalgas supply; naturalgas utilization; advanced coal-based power systems; and advanced fossil fuels research. The subtopics for this solicitation`s NaturalGas Supply topic are (1) drilling, completion, and stimulation; (2) low-permeability Formations; (3) delivery and storage; and (4) naturalgas upgrading.

This issue of the NaturalGas Monthly presents estimates of naturalgas supply and consumption through February 1997. Estimates of naturalgas prices are through November 1996 except electric utility prices that are through October 1996. Cumulatively for January through February 1997, the daily average rates for several data series remain close to those of 1996. (Comparing daily rates accounts for the fact that February 1996 had 29 days.) Daily total consumption for January through February is estimated to be 83 billion cubic feet per day, 1 percent higher than during the same period in 1996. Similarly, the estimate of average daily production of 53 billion cubic feet is 1.5 percent higher than in 1996, while daily net imports during the first 2 months of 1997 are virtually unchanged from 1996.

According to a 1991 Energy Information Administration estimate, U.S. reserves of naturalgas are about 165 trillion cubic feet (TCF). To meet the long-term demand for naturalgas, new gas fields from these reserves will have to be developed. Gas Research Institute studies reveal that 14% (or about 19 TCF) of known reserves in the United States are subquality due to high nitrogen content. Nitrogen-contaminated naturalgas has a low Btu value and must be upgraded by removing the nitrogen. In response to the problem, the Department of Energy is seeking innovative, efficient nitrogen-removal methods. Membrane processes have been considered for naturalgas denitrogenation. The challenge, not yet overcome, is to develop membranes with the required nitrogen/methane separation characteristics. Our calculations show that a methane-permeable membrane with a methane/nitrogen selectivity of 4 to 6 would make denitrogenation by a membrane process viable. The objective of Phase I of this project was to show that membranes with this target selectivity can be developed, and that the economics of the process based on these membranes would be competitive. Gas permeation measurements with membranes prepared from two rubbery polymers and a superglassy polymer showed that two of these materials had the target selectivity of 4 to 6 when operated at temperatures below - 20{degrees}C. An economic analysis showed that a process based on these membranes is competitive with other technologies for small streams containing less than 10% nitrogen. Hybrid designs combining membranes with other technologies are suitable for high-flow, higher-nitrogen-content streams.

This publication, the NaturalGas Monthly, presents the most recent data on naturalgas supply, consumption, and prices from the Energy Information Administration (EIA). Of special interest in this issue are two articles summarizing reports recently published by EIA. The articles are {open_quotes}NaturalGas Productive Capacity{close_quotes} and {open_quotes}Outlook for NaturalGas Through 2015,{close_quotes} both of which precede the {open_quotes}Highlights{close_quotes} section. With this issue, January 1997, changes have been made to the format of the Highlights section and to several of the tabular and graphical presentations throughout the publication. The changes to the Highlights affect the discussion of developments in the industry and the presentation of weekly storage data. An overview of the developments in the industry is now presented in a brief summary followed by specific discussions of supply, end-use consumption, and prices. Spot and futures prices are discussed as appropriate in the Price section, together with wellhead and consumer prices.

The Department of Commerce created a NaturalGas Action Group early in the fall of 1975 to assist industrial firms and the communities they serve to cope with the effects of potentially severe and crippling curtailment situations. This action group was trained to assess a specific local situation, review the potential for remedial action and…

This special report examines the stages of naturalgas processing from the wellhead to the pipeline network through which the raw product becomes ready for transportation and eventual consumption, and how this sequence is reflected in the data published by the Energy Information Administration (EIA).

This document comprises the Department of Energy (DOE) NaturalGas Multi-Year Program Plan, and is a follow-up to the `NaturalGas Strategic Plan and Program Crosscut Plans,` dated July 1995. DOE`s naturalgas programs are aimed at simultaneously meeting our national energy needs, reducing oil imports, protecting our environment, and improving our economy. The NaturalGas Multi-Year Program Plan represents a Department-wide effort on expanded development and use of naturalgas and defines Federal government and US industry roles in partnering to accomplish defined strategic goals. The four overarching goals of the NaturalGas Program are to: (1) foster development of advanced naturalgas technologies, (2) encourage adoption of advanced naturalgas technologies in new and existing markets, (3) support removal of policy impediments to naturalgas use in new and existing markets, and (4) foster technologies and policies to maximize environmental benefits of naturalgas use.

A method of naturalgas liquefaction may include cooling a gaseous NG process stream to form a liquid NG process stream. The method may further include directing the first tail gas stream out of a plant at a first pressure and directing a second tail gas stream out of the plant at a second pressure. An additional method of naturalgas liquefaction may include separating CO.sub.2 from a liquid NG process stream and processing the CO.sub.2 to provide a CO.sub.2 product stream. Another method of naturalgas liquefaction may include combining a marginal gaseous NG process stream with a secondary substantially pure NG stream to provide an improved gaseous NG process stream. Additionally, a NG liquefaction plant may include a first tail gas outlet, and at least a second tail gas outlet, the at least a second tail gas outlet separate from the first tail gas outlet.

A fueling facility and method for dispensing liquid naturalgas (LNG), compressed naturalgas (CNG) or both on-demand. The fueling facility may include a source of LNG, such as cryogenic storage vessel. A low volume high pressure pump is coupled to the source of LNG to produce a stream of pressurized LNG. The stream of pressurized LNG may be selectively directed through an LNG flow path or to a CNG flow path which includes a vaporizer configured to produce CNG from the pressurized LNG. A portion of the CNG may be drawn from the CNG flow path and introduced into the CNG flow path to control the temperature of LNG flowing therethrough. Similarly, a portion of the LNG may be drawn from the LNG flow path and introduced into the CNG flow path to control the temperature of CNG flowing therethrough.

NaturalGas 1995: Issues and Trends addresses current issues affecting the naturalgas industry and markets. Highlights of recent trends include: Naturalgas wellhead prices generally declined throughout 1994 and for 1995 averages 22% below the year-earlier level; Seasonal patterns of naturalgas production and wellhead prices have been significantly reduced during the past three year; Naturalgas production rose 15% from 1985 through 1994, reaching 18.8 trillion cubic feet; Increasing amounts of naturalgas have been imported; Since 1985, lower costs of producing and transporting naturalgas have benefitted consumers; Consumers may see additional benefits as States examine regulatory changes aimed at increasing efficiency; and, The electric industry is being restructured in a fashion similar to the recent restructuring of the naturalgas industry.

This report presents estimates of proved reserves of crude oil, naturalgas, and naturalgas liquids as of December 31, 1997, as well as production volumes for the US and selected States and State subdivisions for the year 1997. Estimates are presented for the following four categories of naturalgas: total gas (wet after lease separation), nonassociated gas and associated-dissolved gas (which are the two major types of wet naturalgas), and total dry gas (wet gas adjusted for the removal of liquids at naturalgas processing plants). In addition, reserve estimates for two types of naturalgas liquids, lease condensate and naturalgas plant liquids, are presented. Also included is information on indicated additional crude oil reserves and crude oil, naturalgas, and lease condensate reserves in nonproducing reservoirs. A discussion of notable oil and gas exploration and development activities during 1997 is provided. 21 figs., 16 tabs.

This publication provides information on the interstate pipeline companies' supply of naturalgas during calendar year 1989, for use by the FERC for regulatory purposes. It also provides information to other Government agencies, the naturalgas industry, as well as policy makers, analysts, and consumers interested in current levels of interstate supplies of naturalgas and trends over recent years. 5 figs., 18 tabs.

The increased level of environmental awareness has raised concerns about pollution. One area of high attention is the internal combustion engine. The internal combustion engine in and of itself is not a major pollution threat. However, the vast number of motor vehicles in use release large quantities of pollutants. Recent technological advances in ignition and engine controls coupled with unleaded fuels and catalytic converters have reduced vehicular emissions significantly. Alternate fuels have the potential to produce even greater reductions in emissions. The NaturalGas Vehicle (NGV) has been a significant alternative to accomplish the goal of cleaner combustion. Of the many alternative fuels under investigation, compressed naturalgas (CNG) has demonstrated the lowest levels of emission. The only vehicle certified by the State of California as an Ultra Low Emission Vehicle (ULEV) was powered by CNG. The California emissions tests of the ULEV-CNG vehicle revealed the following concentrations: Non-Methane Hydrocarbons 0.005 grams/mile Carbon Monoxide 0.300 grams/mile Nitrogen Oxides 0.040 grams/mile. Unfortunately, CNG vehicles will not gain significant popularity until compressed naturalgas is readily available in convenient locations in urban areas and in proximity to the Interstate highway system. Approximately 150,000 gasoline filling stations exist in the United States while number of CNG stations is about 1000 and many of those CNG stations are limited to fleet service only. Discussion in this paper concentrates on CNG flow measurement for fuel dispensers. Since the regulatory changes and market demands affect the flow metering and dispenser station design those aspects are discussed. The CNG industry faces a number of challenges.

This special report looks at the current status of market centers in today's naturalgas marketplace, examining their role and their importance to naturalgas shippers, pipelines, and others involved in the transportation of naturalgas over the North American pipeline network.

The significant growth of Naturalgas based industries in India and elsewhere obviously forced the industry to hunt for new fields and sources. This has naturally led to the phenomenal growth of gas networks. The transportation of gas over thousands of kilometers through caprious ambient conditions requires a great effort. Many difficulties such as condensation of light liquids (NGLS), choking of lines due to formation of hydrates, improper distribution of gas into branches are experienced during pipe line transportation of Naturalgas. The thermodynamic conditions suitable for formation of solid hydrates have been derived depending upon the constituents of naturalgas. Further effects of branching in pipe line transportation have been discussed.

Two major developments in the naturalgas industry are causing fundamental changes in naturalgas contracts. The first development, financial markets for naturalgas, began only recently. On April 3, 1990, the New York Mercantile Exchange (NYMEX) began trading naturalgas futures for a twelve month forward period. On the opening day, 925 contracts were traded. Recently, 18,344 contracts were traded in a single day, and gas 4 futures on NYMEX are now traded for an eighteen month forward period. At the same time, the market for off-exchange products, such as naturalgas swaps and trade options, has expanded considerably. Shortly, it will be hard to imagine life in the naturalgas business without the emerging financial markets for naturalgas, if that time has not already occurred. The second major development, deregulation of the gas industry, began with the passage of the NaturalGas Policy Act of 1978. Each of the two developments provides a catalyst for fundamental changes in naturalgas contracts. This article explores the impact of these two developments on long-term fixed-price physical gas contracts and the future direction of long-term fixed-price gas contracts.

This service report describes the recent behavior of naturalgas markets with respect to naturalgas prices, their potential future behavior, the potential future supply contribution of liquefied naturalgas and increased access to federally restricted resources, and the need for improved naturalgas data.

This report presents estimates of proved reserves of crude oil, naturalgas, and naturalgas liquids as of December 31, 1992, as well as production volumes for the United States, and selected States and State subdivisions for the year 1992. Estimates are presented for the following four categories of naturalgas: total gas (wet after lease separation), its two major components (nonassociated and associated-dissolved gas), and total dry gas (wet gas adjusted for the removal of liquids at naturalgas processing plants). In addition, two components of naturalgas liquids, lease condensate and naturalgas plant liquids, have their reserves and production data presented. Also included is information on indicated additional crude oil reserves and crude oil, naturalgas, and lease condensate reserves in nonproducing reservoirs. A discussion of notable oil and gas exploration and development activities during 1992 is provided.

This thesis analyzes the domestic shortage in the Chinese naturalgas market. Both the domestic supply and demand of naturalgas are growing fast in China. However, the supply cannot catch up with the demand. Under the present pricing mechanism, the Chinese naturalgas market cannot get the equilibrium by itself. Expensive imports are inadequate to fill the increasing gap between the domestic demand and supply. Therefore, the shortage problem occurs. Since the energy gap can result in the arrested development of economics, the shortage problem need to be solved. This thesis gives three suggestions to solve the problem: the use of Unconventional Gas, NaturalGas Storage and Pricing Reform.

The four cases examined in this study have progressively greater impacts on overall naturalgas consumption, prices, and supply. Compared to the Annual Energy Outlook 2004 reference case, the no Alaska pipeline case has the least impact; the low liquefied naturalgas case has more impact; the low unconventional gas recovery case has even more impact; and the combined case has the most impact.

The report provides an overview of major trends occurring in the naturalgas industry and includes a concise look at the drivers behind recent rapid growth in gas usage and the challenges faced in meeting that growth. Topics covered include: an overview of NaturalGas including its history, the current market environment, and its future market potential; an analysis of the overarching trends that are driving a need for change in the NaturalGas industry; a description of new technologies being developed to increase production of NaturalGas; an evaluation of the potential of unconventional NaturalGas sources to supply the market; a review of new transportation methods to get NaturalGas from producing to consuming countries; a description of new storage technologies to support the increasing demand for peak gas; an analysis of the coming changes in global NaturalGas flows; an evaluation of new applications for NaturalGas and their impact on market sectors; and, an overview of NaturalGas trading concepts and recent changes in financial markets.

The technologies and practices that have enabled the recent boom in shale gas production have also brought attention to the environmental impacts of its use. Using the current state of knowledge of the recovery, processing, and distribution of shale gas and conventional naturalgas, we have estimated up-to-date, life-cycle greenhouse gas emissions. In addition, we have developed distribution functions for key parameters in each pathway to examine uncertainty and identify data gaps - such as methane emissions from shale gas well completions and conventional naturalgas liquid unloadings - that need to be addressed further. Our base case results show that shale gas life-cycle emissions are 6% lower than those of conventional naturalgas. However, the range in values for shale and conventional gas overlap, so there is a statistical uncertainty regarding whether shale gas emissions are indeed lower than conventional gas emissions. This life-cycle analysis provides insight into the critical stages in the naturalgas industry where emissions occur and where opportunities exist to reduce the greenhouse gas footprint of naturalgas.

This book is concerned with: the prospects for trade in Western Europe, Japan, the USA and the Third World; the controversial gas pricing issue; and the influence of politics on gas investment and trade. The difficulties of devising fair and enforceable gas contracts between producing and importing countries and the problems arising from government intervention in international negotiations on gas contracts are also considered.

NaturalGas 1998: Issues and Trends provides a summary of the latest data and information relating to the US naturalgas industry, including prices, production, transmission, consumption, and the financial and environmental aspects of the industry. The report consists of seven chapters and five appendices. Chapter 1 presents a summary of various data trends and key issues in today`s naturalgas industry and examines some of the emerging trends. Chapters 2 through 7 focus on specific areas or segments of the industry, highlighting some of the issues associated with the impact of naturalgas operations on the environment. 57 figs., 18 tabs.

The EIA annual reserves report series is the only source of comprehensive domestic proved reserves estimates. This publication is used by the Congress, Federal and State agencies, industry, and other interested parties to obtain accurate estimates of the Nation`s proved reserves of crude oil, naturalgas, and naturalgas liquids. These data are essential to the development, implementation, and evaluation of energy policy and legislation. This report presents estimates of proved reserves of crude oil, naturalgas, and naturalgas liquids as of December 31, 1996, as well as production volumes for the US and selected States and State subdivisions for the year 1996. Estimates are presented for the following four categories of naturalgas: total gas (wet after lease separation), nonassociated gas and associated-dissolved gas (which are the two major types of wet naturalgas), and total dry gas (wet gas adjusted for the removal of liquids at naturalgas processing plants). In addition, reserve estimates for two types of naturalgas liquids, lease condensate and naturalgas plant liquids, are presented. Also included is information on indicated additional crude oil reserves and crude oil, naturalgas, and lease condensate reserves in nonproducing reservoirs. A discussion of notable oil and gas exploration and development activities during 1996 is provided. 21 figs., 16 tabs.

The EIA annual reserves report series is the only source of comprehensive domestic proved reserves estimates. This publication is used by the Congress, Federal and State agencies, industry, and other interested parties to obtain accurate estimates of the Nation`s proved reserves of crude oil, naturalgas, and naturalgas liquids. These data are essential to the development, implementation, and evaluation of energy policy and legislation. This report presents estimates of proved reserves of crude oil, naturalgas, and naturalgas liquids as of December 31, 1995, as well as production volumes for the US and selected States and State subdivisions for the year 1995. Estimates are presented for the following four categories of naturalgas: total gas (wet after lease separation), nonassociated gas and associated-dissolved gas (which are the two major types of wet naturalgas), and total dry gas (wet gas adjusted for the removal of liquids at naturalgas processing plants). In addition, reserve estimates for two types of naturalgas liquids, lease condensate and naturalgas plant liquids, are presented. Also included is information on indicated additional crude oil reserves and crude oil, naturalgas, and lease condensate reserves in nonproducing reservoirs. A discussion of notable oil and gas exploration and development activities during 1995 is provided. 21 figs., 16 tabs.

The NaturalGas Annual provides information on the supply and disposition of naturalgas to a wide audience including industry, consumers, Federal and State agencies, and educational institutions. This report, the NaturalGas Annual 1993 Supplement: Company Profiles, presents a detailed profile of 45 selected companies in the naturalgas industry. The purpose of this report is to show the movement of naturalgas through the various States served by the companies profiled. The companies in this report are interstate pipeline companies or local distribution companies (LDC`s). Interstate pipeline companies acquire gas supplies from company owned production, purchases from producers, and receipts for transportation for account of others. Pipeline systems, service area maps, company supply and disposition data are presented.

The objective of this study is to research technologies and methodologies that will reduce the costs associated with the operation and maintenance of underground naturalgas storage. This effort will include a survey of public information to determine the amount of naturalgas lost from underground storage fields, determine the causes of this lost gas, and develop strategies and remedial designs to reduce or stop the gas loss from selected fields. Phase I includes a detailed survey of US naturalgas storage reservoirs to determine the actual amount of naturalgas annually lost from underground storage fields. These reservoirs will be ranked, the resultant will include the amount of gas and revenue annually lost. The results will be analyzed in conjunction with the type (geologic) of storage reservoirs to determine the significance and impact of the gas loss. A report of the work accomplished will be prepared. The report will include: (1) a summary list by geologic type of US gas storage reservoirs and their annual underground gas storage losses in ft{sup 3}; (2) a rank by geologic classifications as to the amount of gas lost and the resultant lost revenue; and (3) show the level of significance and impact of the losses by geologic type. Concurrently, the amount of storage activity has increased in conjunction with the net increase of naturalgas imports as shown on Figure No. 3. Storage is playing an ever increasing importance in supplying the domestic energy requirements.

The Seaport Liquid NaturalGas Study has attempted to evaluate the potential for using LNG in a variety of heavy-duty vehicle and equipment applications at the Ports of Los Angeles and Oakland. Specifically, this analysis has focused on the handling and transport of containerized cargo to, from and within these two facilities. In terms of containerized cargo throughput, Los Angeles and Oakland are the second and sixth busiest ports in the US, respectively, and together handle nearly 4.5 million TEUs per year. At present, the landside handling and transportation of containerized cargo is heavily dependent on diesel-powered, heavy-duty vehicles and equipment, the utilization of which contributes significantly to the overall emissions impact of port-related activities. Emissions from diesel units have been the subject of increasing scrutiny and regulatory action, particularly in California. In the past two years alone, particulate matter from diesel exhaust has been listed as a toxic air contaminant by CAM, and major lawsuits have been filed against several of California's largest supermarket chains, alleging violation of Proposition 65 statutes in connection with diesel emissions from their distribution facilities. CARE3 has also indicated that it may take further regulatory action relating to the TAC listing. In spite of these developments and the very large diesel emissions associated with port operations, there has been little AFV penetration in these applications. Nearly all port operators interviewed by CALSTART expressed an awareness of the issues surrounding diesel use; however, none appeared to be taking proactive steps to address them. Furthermore, while a less controversial issue than emissions, the dominance of diesel fuel use in heavy-duty vehicles contributes to a continued reliance on imported fuels. The increasing concern regarding diesel use, and the concurrent lack of alternative fuel use and vigorous emissions reduction activity at the Ports provide

The NaturalGas Annual provides information on the supply and disposition of naturalgas to a wide audience including industry, consumers, Federal and State agencies, and educational institutions. This report, Volume 2, presents historical data fro the Nation from 1930 to 1994, and by State from 1967 to 1994.

This report highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. 7 figs., 33 tabs.

This paper examines the discovered and undiscovered Arctic oil and naturalgas resource base with respect to their location and concentration. The paper also discusses the cost and impediments to developing Arctic oil and naturalgas resources, including those issues associated with environmental habitats and political boundaries.

The Majors' Shift to NaturalGas investigates the factors that have guided the United States' major energy producers' growth in U.S. naturalgas production relative to oil production. The analysis draws heavily on financial and operating data from the Energy Information Administration's Financial Reporting System (FRS)

This report highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. 7 figs., 34 tabs.

Petroleum is believed to be unstable in the earth, decomposing to lighter hydrocarbons at temperatures > 150{degrees}C. Oil and gas deposits support this view: gas/oil ratios and methane concentrations tend to increase with depth above 150{degrees}C. Although oil cracking is suggested and receives wide support, laboratory pyrolysis does not give products resembling naturalgas. Moreover, it is doubtful that the light hydrocarbons in wet gas (C{sub 2}-C{sub 4}) could decompose over geologic time to dry gas (>95% methane) without catalytic assistance. We now report the catalytic decomposition of crude oil to a gas indistinguishable from naturalgas. Like naturalgas in deep basins, it becomes progressively enriched in methane: initially 90% (wet gas) to a final composition of 100% methane (dry gas). To our knowledge, the reaction is unprecedented and unexpectedly robust (conversion of oil to gas is 100% in days, 175{degrees}C) with significant implications regarding the stability of petroleum in sedimentary basins. The existence or nonexistence of oil in the deep subsurface may not depend on the thermal stability of hydrocarbons as currently thought. The critical factor could be the presence of transition metal catalysts which destabilize hydrocarbons and promote their decomposition to naturalgas.

This report provides an overview of the naturalgas industry in 1993 and early 1994 (Chapter 1), focusing on the overall ability to deliver gas under the new regulatory mandates of Order 636. In addition, the report highlights a range of issues affecting the industry, including: restructuring under Order 636 (Chapter 2); adjustments in naturalgas contracting (Chapter 3); increased use of underground storage (Chapter 4); effects of the new market on the financial performance of the industry (Chapter 5); continued impacts of major regulatory and legislative changes on the naturalgas market (Appendix A).

The Energy Information Administration (EIA) publishes estimates monthly and annually of the production of naturalgas in the United States. The estimates are based on data EIA collects from gas producing states and data collected by the U. S. Minerals Management Service (MMS) in the Department of Interior. The states and MMS collect this information from producers of naturalgas for various reasons, most often for revenue purposes. Because the information is not sufficiently complete or timely for inclusion in EIA's NaturalGas Monthly (NGM), EIA has developed estimation methodologies to generate monthly production estimates that are described in this document.

The NaturalGas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the naturalgas industry. Volume and price data are presented each month for naturalgas production distribution consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting naturalgas information. The data in this publication are collected on surveys conducted by the EIA to fulfill its responsibilities for gathering and reporting energy data. Some of the data are collected under the authority of the Federal Energy Regulatory Commission (FERC), an independent commission within the DOE, which has jurisdiction primarily in the regulation of electric utilities and the interstate naturalgas industry. Geographic coverage is the 50 States and the District of Columbia.

This report describes work performed during a thirty month project which involves the production of dimethyl ether (DME) on-site for use as an ignition-improving additive in a compression-ignition naturalgas engine. A single cylinder spark ignition engine was converted to compression ignition operation. The engine was then fully instrumented with a cylinder pressure transducer, crank shaft position sensor, airflow meter, naturalgas mass flow sensor, and an exhaust temperature sensor. Finally, the engine was interfaced with a control system for pilot injection of DME. The engine testing is currently in progress. In addition, a one-pass process to form DME from naturalgas was simulated with chemical processing software. Naturalgas is reformed to synthesis gas (a mixture of hydrogen and carbon monoxide), converted into methanol, and finally to DME in three steps. Of additional benefit to the internal combustion engine, the offgas from the pilot process can be mixed with the main naturalgas charge and is expected to improve engine performance. Furthermore, a one-pass pilot facility was constructed to produce 3.7 liters/hour (0.98 gallons/hour) DME from methanol in order to characterize the effluent DME solution and determine suitability for engine use. Successful production of DME led to an economic estimate of completing a full naturalgas-to-DME pilot process. Additional experimental work in constructing a synthesis gas to methanol reactor is in progress. The overall recommendation from this work is that naturalgas to DME is not a suitable pathway to improved naturalgas engine performance. The major reasons are difficulties in handling DME for pilot injection and the large capital costs associated with DME production from naturalgas.

In the United States, recent shale gas discoveries have generated renewed interest in using naturalgas as a vehicular fuel, primarily in fleet applications, while outside the United States, naturalgas vehicle use has expanded significantly in the past decade. In this report for the U.S. Department of Energy's Clean Cities Program - a public-private partnership that advances the energy, economic, and environmental security of the U.S. by supporting local decisions that reduce petroleum use in the transportation sector - we have examined the state of naturalgas vehicle technology, current market status, energy and environmental benefits, implications regarding advancements in European naturalgas vehicle technologies, research and development efforts, and current market barriers and opportunities for greater market penetration. The authors contend that commercial intracity trucks are a prime area for advancement of this fuel. Therefore, we examined an aggressive future market penetration of naturalgas heavy-duty vehicles that could be seen as a long-term goal. Under this scenario using Energy Information Administration projections and GREET life-cycle modeling of U.S. on-road heavy-duty use, naturalgas vehicles would reduce petroleum consumption by approximately 1.2 million barrels of oil per day, while another 400,000 barrels of oil per day reduction could be achieved with significant use of naturalgas off-road vehicles. This scenario would reduce daily oil consumption in the United States by about 8%.

The discovery of large gas hydrate accumulations in terrestrial permafrost regions of the Arctic and beneath the sea along the outer continental margins of the world's oceans has heightened interest in gas hydrates as a possible energy resource. However, significant to potentially insurmountable technical issues must be resolved before gas hydrates can be considered a viable option for affordable supplies of naturalgas. The combined information from Arctic gas hydrate studies shows that, in permafrost regions, gas hydrates may exist at subsurface depths ranging from about 130 to 2000 m. The presence of gas hydrates in offshore continental margins has been inferred mainly from anomalous seismic reflectors, known as bottom-simulating reflectors, that have been mapped at depths below the sea floor ranging from about 100 to 1100 m. Current estimates of the amount of gas in the world's marine and permafrost gas hydrate accumulations are in rough accord at about 20,000 trillion m3. Disagreements over fundamental issues such as the volume of gas stored within delineated gas hydrate accumulations and the concentration of gas hydrates within hydrate-bearing strata have demonstrated that we know little about gas hydrates. Recently, however, several countries, including Japan, India, and the United States, have launched ambitious national projects to further examine the resource potential of gas hydrates. These projects may help answer key questions dealing with the properties of gas hydrate reservoirs, the design of production systems, and, most important, the costs and economics of gas hydrate production.

This report addresses the {open_quotes}contracts portfolio{close_quotes} issue of naturalgas contracts in support of the Domestic NaturalGas and Oil Initiative (DGOI) published by the U.S. Department of Energy in 1994. The analysis is a result of a collaborative effort with the Public Service Commission of the State of Maryland to consider {open_quotes}reforms that enhance the industry`s competitiveness{close_quotes}. The initial focus of our collaborative effort was on gas purchasing and contract portfolios; however, it became apparent that efficient contracting to purchase and use gas requires a broader consideration of regulatory reform. Efficient portfolios are obtained when the holder of the portfolio is affected by and is responsible for the performance of the portfolio. Naturalgas distribution companies may prefer a diversity of contracts, but the efficient use of gas requires that the local distribution company be held accountable for its own purchases. Ultimate customers are affected by their own portfolios, which they manage efficiently by making their own choices. The objectives of the DGOI, particularly the efficient use of gas, can be achieved when customers have access to suppliers of gas and energy services under an improved regulatory framework. The evolution of the naturalgas market during the last 15 years is described to account for the changing preferences toward gas contracts. Long-term contracts for naturalgas were prevalent before the early 1980s, primarily because gas producers had few options other than to sell to a single pipeline company, and this pipeline company, in turn, was the only seller to a gas distribution company.

This report sunnnarizes the research by an Energy Modeling Forum working group on the evolution of the North American naturalgas markets between now and 2010. The group`s findings are based partly on the results of a set of economic models of the naturalgas industry that were run for four scenarios representing significantly different conditions: two oil price scenarios (upper and lower), a smaller total US resource base (low US resource case), and increased potential gas demand for electric generation (high US demand case). Several issues, such as the direction of regulatory policy and the size of the gas resource base, were analyzed separately without the use of models.

This report summarizes die research by an Energy Modeling Forum working group on the evolution of the North American naturalgas markets between now and 2010. The group`s findings are based partly on the results of a set of economic models of the naturalgas industry that were run for four scenarios representing significantly different conditions: two oil price scenarios (upper and lower), a smaller total US resource base (low US resource case), and increased potential gas demand for electric generation (high US demand case). Several issues, such as the direction of regulatory policy and the size of the gas resource base, were analyzed separately without the use of models.

In 1999 the Pacific Gas and Electric Gas Transmission Northwest (GTN) drilled a borehole to investigate the feasibility of developing a naturalgas-storage facility in a structural dome formed in Columbia River basalts in the Columbia Basin of south-central Washington State. The proposed aquifer storage facility will be an unconventional one where naturalgas will be initially injected (and later retrieved) in one or multiple previous horizons (interflow zones) that are confined between deep (>700 meters) basalt flows of the Columbia River Basalt Group. This report summarizes the results of joint investigations on that feasibility study by GTN and the US Department of Energy.

The unavailability of naturalgas vehicle (NGV) refueling stations constitutes one of the major barriers to the wide spread utilization of naturalgas in the transportation market. The purpose of this paper is to review and evaluate the current technical and economic status of compressed naturalgas vehicle refueling stations and to identify the components or design features that offer the greatest potential for performance improvements and/or cost reductions. Both fast-fill- and slow-fill-type refueling systems will be discussed. 4 refs., 10 figs., 6 tabs.

A review of current naturalgas vehicle offerings is presented for both light-duty and medium- and heavy-duty applications. Recent gaps in the marketplace are discussed, along with how they have been or may be addressed. The stakeholder input process for guiding research and development needs via the NaturalGas Vehicle Technology Forum (NGVTF) to the U.S. Department of Energy and the California Energy Commission is reviewed. Current high-level naturalgas engine development gap areas are highlighted, including efficiency, emissions, and the certification process.

This document provides information on the supply and disposition of naturalgas to a wide audience including industry, consumers, Federal and State agencies, and education institutions. The 1992 data are presented in a sequence that follows naturalgas (including supplemental supplies) from its production top its end use. Tables summarizing naturalgas supply and disposition from 1988 to 1992 are given for each Census Division and each State. Annual historical data are shown at the national level. Volume 2 of this report presents State-level historical data.

A new project was initiated this quarter to develop gas/liquid membranes for naturalgas upgrading. Efforts have concentrated on legal agreements, including alternative field sites. Gas Technology Institute (GTI) is conducting this research program whose objective is to develop gas/liquid membranes for naturalgas upgrading to assist DOE in achieving their goal of developing novel methods of upgrading low quality naturalgas to meet pipeline specifications. Kvaerner Process Systems (KPS) and W. L. Gore & Associates (GORE) gas/liquid membrane contactors are based on expanded polytetrafluoroethylene (ePTFE) membranes acting as the contacting barrier between the contaminated gas stream and the absorbing liquid. These resilient membranes provide much greater surface area for transfer than other tower internals, with packing densities five to ten times greater, resulting in equipment 50-70% smaller and lower weight for the same treating service. The scope of the research program is to (1) build and install a laboratory- and a field-scale gas/liquid membrane absorber; (2) operate the units with a low quality naturalgas feed stream for sufficient time to verify the simulation model of the contactors and to project membrane life in this severe service; and (3) conducted an economic evaluation, based on the data, to quantify the impact of the technology. Chevron, one of the major producers of naturalgas, has offered to host the test at a gas treating plant. KPS will use their position as a recognized leader in the construction of commercial amine plants for building the unit along with GORE providing the membranes. GTI will provide operator and data collection support during lab- and field-testing to assure proper analytical procedures are used. Kvaerner and GTI will perform the final economic evaluation. GTI will provide project management and be responsible for reporting and interactions with DOE on this project.

Gas hydrates are crystalline substances composed of water and gas, in which a solid-water-lattice accommodates gas molecules in a cage-like structure. Gas hydrates are globally widespread in permafrost regions and beneath the sea in sediment of outer continental margins. While methane, propane, and other gases can be included in the clathrate structure, methane hydrates appear to be the most common in nature. The amount of methane sequestered in gas hydrates is probably enormous, but estimates are speculative and range over three orders of magnitude from about 100,000 to 270,000,000 trillion cubic feet. The amount of gas in the hydrate reservoirs of the world greedy exceeds the volume of known conventional gas reserves. Gas hydrates also represent a significant drilling and production hazard. A fundamental question linking gas hydrate resource and hazard issues is: What is the volume of gas hydrates and included gas within a given gas hydrate occurrence Most published gas hydrate resource estimates have, of necessity, been made by broad extrapolation of only general knowledge of local geologic conditions. Gas volumes that may be attributed to gas hydrates are dependent on a number of reservoir parameters, including the areal extent ofthe gas-hydrate occurrence, reservoir thickness, hydrate number, reservoir porosity, and the degree of gas-hydrate saturation. Two of the most difficult reservoir parameters to determine are porosity and degreeof gas hydrate saturation. Well logs often serve as a source of porosity and hydrocarbon saturation data; however, well-log calculations within gas-hydrate-bearing intervals are subject to error. The primary reason for this difficulty is the lack of quantitative laboratory and field studies. The primary purpose of this paper is to review the response of well logs to the presence of gas hydrates.

Gas hydrates are crystalline substances composed of water and gas, in which a solid-water-lattice accommodates gas molecules in a cage-like structure. Gas hydrates are globally widespread in permafrost regions and beneath the sea in sediment of outer continental margins. While methane, propane, and other gases can be included in the clathrate structure, methane hydrates appear to be the most common in nature. The amount of methane sequestered in gas hydrates is probably enormous, but estimates are speculative and range over three orders of magnitude from about 100,000 to 270,000,000 trillion cubic feet. The amount of gas in the hydrate reservoirs of the world greedy exceeds the volume of known conventional gas reserves. Gas hydrates also represent a significant drilling and production hazard. A fundamental question linking gas hydrate resource and hazard issues is: What is the volume of gas hydrates and included gas within a given gas hydrate occurrence? Most published gas hydrate resource estimates have, of necessity, been made by broad extrapolation of only general knowledge of local geologic conditions. Gas volumes that may be attributed to gas hydrates are dependent on a number of reservoir parameters, including the areal extent ofthe gas-hydrate occurrence, reservoir thickness, hydrate number, reservoir porosity, and the degree of gas-hydrate saturation. Two of the most difficult reservoir parameters to determine are porosity and degreeof gas hydrate saturation. Well logs often serve as a source of porosity and hydrocarbon saturation data; however, well-log calculations within gas-hydrate-bearing intervals are subject to error. The primary reason for this difficulty is the lack of quantitative laboratory and field studies. The primary purpose of this paper is to review the response of well logs to the presence of gas hydrates.

The objectives of the Infield Growth/Secondary NaturalGas Recovery project have been: To establish how depositional and diagenetic heterogeneities in reservoirs of conventional permeability cause reservoir compartmentalization and, hence, incomplete recovery of naturalgas. To document practical, field-oriented examples of reserve growth from fluvial and deltaic sandstones of the Texas gulf coast basin and to use these gas reservoirs as a natural laboratory for developing concepts and testing applications of both tools and techniques to find secondary gas. To demonstrate how the integration of geology, reservoir engineering, geophysics, and well log analysis/petrophysics leads to strategic recompletion and well placement opportunities for reserve growth in mature fields. To transfer project results to naturalgas producers, not just as field case studies, but as conceptual models of how heterogeneities determine naturalgas flow and how to recognize the geologic and engineering clues that operators can use in a cost-effective manner to identify secondary gas. Accomplishments are presented for: reservoir characterization; integrated formation evaluation and engineering testing; compartmented reservoir simulator; and reservoir geophysics.

An efficient method of producing hydrogen by high temperature steam electrolysis that will lower the electricity consumption to an estimated 65 percent lower than has been achievable with previous steam electrolyzer systems. This is accomplished with a naturalgas-assisted steam electrolyzer, which significantly reduces the electricity consumption. Since this naturalgas-assisted steam electrolyzer replaces one unit of electrical energy by one unit of energy content in naturalgas at one-quarter the cost, the hydrogen production cost will be significantly reduced. Also, it is possible to vary the ratio between the electricity and the naturalgas supplied to the system in response to fluctuations in relative prices for these two energy sources. In one approach an appropriate catalyst on the anode side of the electrolyzer will promote the partial oxidation of naturalgas to CO and hydrogen, called Syn-Gas, and the CO can also be shifted to CO.sub.2 to give additional hydrogen. In another approach the naturalgas is used in the anode side of the electrolyzer to burn out the oxygen resulting from electrolysis, thus reducing or eliminating the potential difference across the electrolyzer membrane.

With gasoline being an ever decreasing finite resource and with the desire to reduce humanity's carbon footprint, there has been an increasing focus on innovation of alternative fuel sources. Naturalgas burns cleaner, is more abundant, and conforms to modern engines. However, storing compressed naturalgas (CNG) requires large, heavy gas cylinders, which limits space and fuel efficiency. Adsorbed naturalgas (ANG) technology allows for much greater fuel storage capacity and the ability to store the gas at a much lower pressure. Thus, ANG tanks are much more flexible in terms of their size, shape, and weight. Our ANG tank employs monolithic nanoporous activated carbon as its adsorbent material. Several different configurations of this Flat Panel Tank Assembly (FPTA) along with a Fuel Extraction System (FES) were examined to compare with the mass flow rate demands of an engine.

A series of computations has been made to produce the equilibrium temperature and gas composition for naturalgas fuel and dry air. The computed tables and figures provide combustion gas property data for pressures from 0.5 to 50 atmospheres and equivalence ratios from 0 to 2.0. Only samples tables and figures are provided in this report. The complete set of tables and figures is provided on four microfiche films supplied with this report.

This publication presents a summary of the latest data and information relating to the U.S. naturalgas industry, including prices, production, transmission, consumption, and financial aspects of the industry.

This patent describes a method of dismantling a naturalgas holder. The holder has vertical support columns disposed around the periphery of the holder to which the enclosure shell of the holder is attached.

This thesis analyzes demand in the US energy market for naturalgas, oil, and coal over the period of 1918-2013 and examines their price relationship over the period of 2007-2013. Diagnostic tests for time series were used; Augmented Dickey-Fuller, Kwiatkowski-Phillips-Schmidt-Shin, Johansen cointegration, Granger Causality and weak exogeneity tests. Directed acyclic graphs were used as a complimentary test for endogeneity. Due to the varied results in determining endogeneity, a seemingly unrelated regression model was used which assumes all right hand side variables in the three demand equations were exogenous. A number of factors were significant in determining demand for naturalgas including its own price, lagged demand, a number of structural break dummies, and trend, while oil indicate some substitutability with naturalgas. An error correction model was used to examine the price relationships. Naturalgas price was found not to have a significant cointegrating vector.

Empirical method for calculating both the mass flow rate and upstream volume flow rate through critical flow nozzles is determined. Method requires knowledge of the composition of naturalgas, and of the upstream pressure and temperature.

The data for the NaturalGas Annual 1991 Supplement : Company Profiles are taken from Form EIA-176, (open quotes) Annual Report of Natural and Supplemental Gas Supply and Disposition (close quotes). Other sources include industry literature and corporate annual reports to shareholders. The companies appearing in this report are major interstate naturalgas pipeline companies, large distribution companies, or combination companies with both pipeline and distribution operations. The report contains profiles of 45 corporate families. The profiles describe briefly each company, where it operates, and any important issues that the company faces. The purpose of this report is to show the movement of naturalgas through the various States served by the 45 large companies profiled.

This report provides an overview of the naturalgas industry in 1991 and 1992, focusing on trends in production, consumption, and pricing of naturalgas and how they reflect the regulatory and legislative changes of the past decade (Chapter 1). Also presented are details of FERC Order 636 and the Energy Policy Act of 1992, as well as pertinent provisions of the Clean Air Act Amendments of 1990 (Chapter 2). In addition, the report highlights a range of issues affecting the industry, including: Trends in wellhead prices and naturalgas supply activities (Chapter 3); Recent rate design changes for interstate pipeline companies (Chapter 4); Benefits to consumers from the more competitive marketplace (Chapter 5); Pipeline capacity expansions during the past 2 years (Chapter 6); Increasing role of the naturalgas futures market (Chapter 7).

It is broadly accepted that so-called 'thermal' gas is the product of thermal cracking, 'primary' thermal gas from kerogen cracking, and 'secondary' thermal gas from oil cracking. Since thermal cracking of hydrocarbons does not generate products at equilibrium and thermal stress should not bring them to equilibrium over geologic time, we would not expect methane, ethane, and propane to be at equilibrium in subsurface deposits. Here we report compelling evidence of naturalgas at thermodynamic equilibrium. Molecular compositions are constrained to equilibrium, and isotopic compositions are also under equilibrium constraints: The functions [(CH4)*(C3H8)] and [(C2H6)2] exhibit a strong nonlinear correlation (R2 = 0.84) in which the quotient Q progresses to K as wet gas progresses to dry gas. There are striking similarities between naturalgas and catalytic gas generated from marine shales. A Devonian/Mississippian New Albany shale generates gas with Q converging on K over time as wet gas progresses to dry gas at 200°C. The position that thermal cracking is the primary source of naturalgas is no longer tenable. It is challenged by its inability to explain the composition of naturalgas, natural gases at thermodynamic equilibrium, and by the existence of a catalytic path to gas that better explains gas compositions. PMID:19531233

A new process economically converts naturalgas into synthetic transportation fuels that are free of sulfur, metals, aromatics and are clear in appearance. The process, developed by Syntroleum Corp., is energy self-sufficient and can be implemented in sizes small enough to fit a large number of the world`s gas fields. The process is described.

Gas Technology Institute (GTI) is conducting this research program whose objective is to develop gas/liquid membranes for naturalgas upgrading to assist DOE in achieving their goal of developing novel methods of upgrading low quality naturalgas to meet pipeline specifications. Kvaerner Process Systems (KPS) and W. L. Gore & Associates (GORE) gas/liquid membrane contactors are based on expanded polytetrafluoroethylene (ePTFE) membranes acting as the contacting barrier between the contaminated gas stream and the absorbing liquid. These resilient membranes provide much greater surface area for transfer than other tower internals, with packing densities five to ten times greater, resulting in equipment 50-70% smaller and lower weight for the same treating service. The scope of the research program is to (1) build and install a laboratory- and a field-scale gas/liquid membrane absorber; (2) operate the units with a low quality naturalgas feed stream for sufficient time to verify the simulation model of the contactors and to project membrane life in this severe service; and (3) conducted an economic evaluation, based on the data, to quantify the impact of the technology. Chevron, one of the major producers of naturalgas, has offered to host the test at a gas treating plant. KPS will use their position as a recognized leader in the construction of commercial amine plants for building the unit along with GORE providing the membranes. GTI will provide operator and data collection support during lab- and field-testing to assure proper analytical procedures are used. KPS and GTI will perform the final economic evaluation. GTI will provide project management and be responsible for reporting and interactions with DOE on this project. Efforts this quarter have concentrated on field site selection. ChevronTexaco has nominated their Headlee Gas Plant in Odessa, TX for a commercial-scale dehydration test. Potting and module materials testing were initiated. Preliminary design

... Granting Authority To Import and Export NaturalGas, and To Import Liquefied NaturalGas During June 2013... authority to import and export naturalgas and to import liquefied naturalgas. These orders are summarized... of Fossil Energy, Office of NaturalGas Regulatory Activities, Docket Room 3E-033, Forrestal...

The rapid deployment of hydraulic fracturing and horizontal drilling technologies enabled the production of previously uneconomic shale gas resources in North America. Global deployment of these advanced gas production technologies could bring large influx of economically competitive unconventional gas resources to the energy system. It has been hoped that abundant naturalgas substituting for coal could reduce carbon dioxide (CO2) emissions, which in turn could reduce climate forcing. Other researchers countered that the non-CO2 greenhouse gas (GHG) emissions associated with shale gas production make its lifecycle emissions higher than those of coal. In this study, we employ five state-of-the-art integrated assessment models (IAMs) of energy-economy-climate systems to assess the full impact of abundant gas on climate change. The models show large additional naturalgas consumption up to +170% by 2050. The impact on CO2 emissions, however, is found to be much smaller (from -2% to +11%), and a majority of the models reported a small increase in climate forcing (from -0.3% to +7%) associated with the increased use of abundant gas. Our results show that while globally abundant gas may substantially change the future energy market equilibrium, it will not significantly mitigate climate change on its own in the absence of climate policies.

Ultra Centrifuge Nederland N.V.'s improved centrifuge for separating helium from naturalgas comprises a hollow cylindrical rotor, designated as a separating drum, within a stationary housing. Naturalgas liquids that condense under pressure in the separating drum pass through openings in the drum into the space between the drum and housing. In this space, a series of openings, or throttling restrictors, allows the liquids to expand and return to gas. The gaseous component that does not liquefy in the drum remains separate for drawing off.

From a geological perspective, deep naturalgas resources are generally defined as resources occurring in reservoirs at or below 15,000 feet, whereas ultra-deep gas occurs below 25,000 feet. From an operational point of view, ''deep'' is often thought of in a relative sense based on the geologic and engineering knowledge of gas (and oil) resources in a particular area. Deep gas can be found in either conventionally-trapped or unconventional basin-center accumulations that are essentially large single fields having spatial dimensions often exceeding those of conventional fields. Exploration for deep conventional and unconventional basin-center naturalgas resources deserves special attention because these resources are widespread and occur in diverse geologic environments. In 1995, the U.S. Geological Survey estimated that 939 TCF of technically recoverable naturalgas remained to be discovered or was part of reserve appreciation from known fields in the onshore areas and State waters of the United. Of this USGS resource, nearly 114 trillion cubic feet (Tcf) of technically-recoverable gas remains to be discovered from deep sedimentary basins. Worldwide estimates of deep gas are also high. The U.S. Geological Survey World Petroleum Assessment 2000 Project recently estimated a world mean undiscovered conventional gas resource outside the U.S. of 844 Tcf below 4.5 km (about 15,000 feet). Less is known about the origins of deep gas than about the origins of gas at shallower depths because fewer wells have been drilled into the deeper portions of many basins. Some of the many factors contributing to the origin of deep gas include the thermal stability of methane, the role of water and non-hydrocarbon gases in naturalgas generation, porosity loss with increasing thermal maturity, the kinetics of deep gas generation, thermal cracking of oil to gas, and source rock potential based on thermal maturity and kerogen type. Recent experimental simulations using laboratory

We publish this volume at a time when there is a growing interest in gas hydrates and major expansion in international research efforts. The first recognition of naturalgas hydrate on land in Arctic conditions was in the mid-1960s (by I. Makogon) and in the seabed environment only in the early 1970s, after natural seafloor gas hydrate was drilled on the Blake Ridge during Deep Sea Drilling Project Leg 11. Initial scientific investigations were slow to develop because the study of naturalgas hydrates is unusually challenging. Gas hydrate exists in nature in conditions of temperature and pressure where human beings cannot survive, and if gas hydrate is transported from its region of stability to normal Earth-surface conditions, it dissociates. Thus, in contrast to most minerals, we cannot depend on drilled samples to provide accurate estimates of the amount of gas hydrate present. Even the heat and changes in chemistry (methane saturation, salinity, etc.) introduced by the drilling process affect the gas hydrate, independent of the changes brought about by moving a sample to the surface. Gas hydrate has been identified in nature generally by inference from indirect evidence in drilling data or by using remotely sensed indications, mostly from seismic data. Obviously, the established techniques ofgeologic analysis, which require direct observation and sampling, do not apply to gas hydrate studies, and controversy has surrounded many interpretations. Pressure/temperature conditions appropriate for the existence of gas hydrate occur over the greater part of the shallow subsurface of the Earth beneath the ocean at water depths exceeding about 500 m (shallower beneath colder Arctic seas) and on land beneath high-latitude permafrost. Gas hydrate actually will be present in such conditions, however, only where methane is present at high concentrations. In the Arctic, these methane concentrations are often associated with petroleum deposits, whereas at continental margins

This special report examines recent expansions to the North American naturalgas pipeline network and the nature and type of proposed pipeline projects announced or approved for construction during the next several years in the United States. It includes those projects in Canada and Mexico that tie in with U.S. markets or projects.

Gas Technology Institute (GTI) is conducting this research program whose objective is to develop gas/liquid membranes for naturalgas upgrading to assist DOE in achieving their goal of developing novel methods of upgrading low quality naturalgas to meet pipeline specifications. Kvaerner Process Systems (KPS) and W. L. Gore & Associates (GORE) gas/liquid membrane contactors are based on expanded polytetrafluoroethylene (ePTFE) membranes acting as the contacting barrier between the contaminated gas stream and the absorbing liquid. These resilient membranes provide much greater surface area for transfer than other tower internals, with packing densities five to ten times greater, resulting in equipment 50-70% smaller and lower weight for the same treating service. The scope of the research program is to (1) build and install a laboratory- and a field-scale gas/liquid membrane absorber; (2) operate the units with a low quality naturalgas feed stream for sufficient time to verify the simulation model of the contactors and to project membrane life in this severe service; and (3) conducted an economic evaluation, based on the data, to quantify the impact of the technology. Chevron, one of the major producers of naturalgas, has offered to host the test at a gas treating plant. KPS will use their position as a recognized leader in the construction of commercial amine plants for building the unit along with GORE providing the membranes. GTI will provide operator and data collection support during lab- and field-testing to assure proper analytical procedures are used. Kvaerner and GTI will perform the final economic evaluation. GTI will provide project management and be responsible for reporting and interactions with DOE on this project. Efforts this quarter have concentrated on legal agreements, including alternative field sites. Preliminary design of the bench-scale equipment continues.

Efforts this quarter have concentrated on legal agreements, including alternative field sites. Preliminary design of the bench-scale equipment continues. Gas Technology Institute (GTI) is conducting this research program whose objective is to develop gas/liquid membranes for naturalgas upgrading to assist DOE in achieving their goal of developing novel methods of upgrading low quality naturalgas to meet pipeline specifications. Kvaerner Process Systems (KPS) and W. L. Gore & Associates (GORE) gas/liquid membrane contactors are based on expanded polytetrafluoroethylene (ePTFE) membranes acting as the contacting barrier between the contaminated gas stream and the absorbing liquid. These resilient membranes provide much greater surface area for transfer than other tower internals, with packing densities five to ten times greater, resulting in equipment 50--70% smaller and lower weight for the same treating service. The scope of the research program is to (1) build and install a laboratory- and a field-scale gas/liquid membrane absorber; (2) operate the units with a low quality naturalgas feed stream for sufficient time to verify the simulation model of the contactors and to project membrane life in this severe service; and (3) conducted an economic evaluation, based on the data, to quantify the impact of the technology. Chevron, one of the major producers of naturalgas, has offered to host the test at a gas treating plant. KPS will use their position as a recognized leader in the construction of commercial amine plants for building the unit along with GORE providing the membranes. GTI will provide operator and data collection support during lab- and field-testing to assure proper analytical procedures are used. Kvaerner and GTI will perform the final economic evaluation. GTI will provide project management and be responsible for reporting and interactions with DOE on this project.

Efforts this quarter have concentrated on legal agreements, including alternative field sites. Preliminary design of the bench-scale equipment has been initiated. Gas Technology Institute (GTI) is conducting this research program whose objective is to develop gas/liquid membranes for naturalgas upgrading to assist DOE in achieving their goal of developing novel methods of upgrading low quality naturalgas to meet pipeline specifications. Kvaerner Process Systems (KPS) and W. L. Gore & Associates (GORE) gas/liquid membrane contactors are based on expanded polytetrafluoroethylene (ePTFE) membranes acting as the contacting barrier between the contaminated gas stream and the absorbing liquid. These resilient membranes provide much greater surface area for transfer than other tower internals, with packing densities five to ten times greater, resulting in equipment 50--70% smaller and lower weight for the same treating service. The scope of the research program is to (1) build and install a laboratory- and a field-scale gas/liquid membrane absorber; (2) operate the units with a low quality naturalgas feed stream for sufficient time to verify the simulation model of the contactors and to project membrane life in this severe service; and (3) conducted an economic evaluation, based on the data, to quantify the impact of the technology. Chevron, one of the major producers of naturalgas, has offered to host the test at a gas treating plant. KPS will use their position as a recognized leader in the construction of commercial amine plants for building the unit along with GORE providing the membranes. GTI will provide operator and data collection support during lab- and field-testing to assure proper analytical procedures are used. Kvaerner and GTI will perform the final economic evaluation. GTI will provide project management and be responsible for reporting and interactions with DOE on this project.

Gas Technology Institute (GTI) is conducting this research program whose objective is to develop gas/liquid membranes for naturalgas upgrading to assist DOE in achieving their goal of developing novel methods of upgrading low quality naturalgas to meet pipeline specifications. Kvaerner Process Systems (KPS) and W. L. Gore & Associates (GORE) gas/liquid membrane contactors are based on expanded polytetrafluoroethylene (ePTFE) membranes acting as the contacting barrier between the contaminated gas stream and the absorbing liquid. These resilient membranes provide much greater surface area for transfer than other tower internals, with packing densities five to ten times greater, resulting in equipment 50-70% smaller and lower weight for the same treating service. The scope of the research program is to (1) build and install a laboratory- and a field-scale gas/liquid membrane absorber; (2) operate the units with a low quality naturalgas feed stream for sufficient time to verify the simulation model of the contactors and to project membrane life in this severe service; and (3) conducted an economic evaluation, based on the data, to quantify the impact of the technology. Chevron, one of the major producers of naturalgas, has offered to host the test at a gas treating plant. KPS will use their position as a recognized leader in the construction of commercial amine plants for building the unit along with GORE providing the membranes. GTI will provide operator and data collection support during lab- and field-testing to assure proper analytical procedures are used. KPS and GTI will perform the final economic evaluation. GTI will provide project management and be responsible for reporting and interactions with DOE on this project. Efforts this quarter have concentrated on legal agreements, including alternative field sites. Preliminary design of the bench-scale equipment continues.

Naturalgas (all of it domestically produced) was the largest single source of Pakistan's 1980 energy supply, contributing 40.1% of the total, compared with 37.4% for oil, 16.6% for hydroelectricity, 5.6% for coal, and 0.3% for LP-gas, plus a very small amount of nuclear power. In 1979, gas accounted for 37.6% of the total and oil for 38.9%. Eighty percent of Pakistan's total naturalgas production of nearly 300 billion CF came from the Sui field in central Pakistan, which is being developed by Pakistan Petroleum Ltd. The balance was produced in Esso's Mari field and the Oil and Gas Development Commission's Sari and Hundi fields.

LDEF (Postflight), AO175 : Evaluation of Long-Duration Exposure to the Natural Space Environment on Graphite-Polyimide and Graphite-Epoxy Mechanical Properties, Tray A01 The Graphite-Polyimide and Graphite-Epoxy Mechanical Properties experiment postflight photograph was taken in the Orbiter Processing Facility during the period when the LDEF was being transferred from the Orbiter cargo bay to the KSC Payload Transporter. The photograph shows considerably more detail than the flight photograph. The horizontal lines on the honeycomb panel that appear to be cracks from space exposure are instead fine lines of excess epoxy resin formed during the bagging and curing process. The harsh white color of the epoxy adhesive along the rivet lines is from the lighting conditions in the OPF. The brown discoloration on the paint dots and the stain on the aluminum mounting strips appear to have changed little from the flight photograph. The greater detail does show that a stain exists at most composite and mounting strip interfaces.

In 1995, the USGS estimated a mean resource of 114 trillion cubic feet of undiscovered technically recoverable naturalgas in plays deeper than 15,000 feet/4,572 meters in onshore regions of the United States. This volume summarizes major conclusions of ongoing work. Chapters A and B address the areal extent of drilling and distribution of deep basins in the U.S. Chapter C summarizes distribution of deep sedimentary basins and potential for deep gas in the former Soviet Union. Chapters D and E are geochemical papers addressing source-rock issues and deep gas generation. Chapter F develops a probabilistic method for subdividing gas resources into depth slices, and chapter G analyzes the relative uncertainty of estimates of deep gas in plays in the Gulf Coast Region. Chapter H evaluates the mechanism of hydrogenation of deep, high-rank spent kerogen by water, with subsequent generation of methane-rich HC gas.

This paper evaluates the accuracy of two methods to forecast naturalgas prices: using the Energy Information Administration's ''Annual Energy Outlook'' forecasted price (AEO) and the ''Henry Hub'' compared to U.S. Wellhead futures price. A statistical analysis is performed to determine the relative accuracy of the two measures in the recent past. A statistical analysis suggests that the Henry Hub futures price provides a more accurate average forecast of naturalgas prices than the AEO. For example, the Henry Hub futures price underestimated the naturalgas price by 35 cents per thousand cubic feet (11.5 percent) between 1996 and 2003 and the AEO underestimated by 71 cents per thousand cubic feet (23.4 percent). Upon closer inspection, a liner regression analysis reveals that two distinct time periods exist, the period between 1996 to 1999 and the period between 2000 to 2003. For the time period between 1996 to 1999, AEO showed a weak negative correlation (R-square = 0.19) between forecast price by actual U.S. Wellhead naturalgas price versus the Henry Hub with a weak positive correlation (R-square = 0.20) between forecasted price and U.S. Wellhead naturalgas price. During the time period between 2000 to 2003, AEO shows a moderate positive correlation (R-square = 0.37) between forecasted naturalgas price and U.S. Wellhead naturalgas price versus the Henry Hub that show a moderate positive correlation (R-square = 0.36) between forecast price and U.S. Wellhead naturalgas price. These results suggest that agencies forecasting naturalgas prices should consider incorporating the Henry Hub naturalgas futures price into their forecasting models along with the AEO forecast. Our analysis is very preliminary and is based on a very small data set. Naturally the results of the analysis may change, as more data is made available.

The technologies and practices that have enabled the recent boom in shale gas production have also brought attention to the environmental impacts of its use. It has been debated whether the fugitive methane emissions during naturalgas production and transmission outweigh the lower carbon dioxide emissions during combustion when compared to coal and petroleum. Using the current state of knowledge of methane emissions from shale gas, conventional naturalgas, coal, and petroleum, we estimated up-to-date life-cycle greenhouse gas emissions. In addition, we developed distribution functions for key parameters in each pathway to examine uncertainty and identify data gaps such as methane emissions from shale gas well completions and conventional naturalgas liquid unloadings that need to be further addressed. Our base case results show that shale gas life-cycle emissions are 6% lower than conventional naturalgas, 23% lower than gasoline, and 33% lower than coal. However, the range in values for shale and conventional gas overlap, so there is a statistical uncertainty whether shale gas emissions are indeed lower than conventional gas. Moreover, this life-cycle analysis, among other work in this area, provides insight on critical stages that the naturalgas industry and government agencies can work together on to reduce the greenhouse gas footprint of naturalgas. PMID:22107036

The NaturalGas for Vehicles (NGV) Project in Venezuela describes the development and growth of the NGV project in the country. Venezuela is a prolific oil producer with advanced exploration, production, refining and solid marketing infrastructure. Gas production is 5.2 Bscfd. The Venezuelan Government and the oil state owned company Petroleos de Venezuela (PDVSA), pursued the opportunity of using naturalgas for vehicles based on the huge amounts of gas reserves present and produced every day associated with the oil production. A nationwide gas pipeline network crosses the country from south to west reaching the most important cities and serving domestic and industrial purposes but there are no facilities to process or export liquefied naturalgas. NGV has been introduced gradually in Venezuela over the last eight years by PDVSA. One hundred forty-five NGV stations have been installed and another 25 are under construction. Work done comprises displacement or relocation of existing gasoline equipment, civil work, installation and commissioning of equipment. The acceptance and usage of the NGV system is reflected in the more than 17,000 vehicles that have been converted to date using the equivalent of 2,000 bbl oil/day.

Prices for naturalgas at the wellhead, city gate and burner tip peaked in 1984-1985. Market softness and surplus capability (the bubble) were the contributing factors. This year, it is expected that these same factors, plus the pressure of increased imports from Canada, will drive marginal prices down even further, to below $1.75 per MCF before the market finally finds bottom. Spot sales in 1985, at ever lower prices, proliferated as producers engaging in severe gas-to-gas competition sought buyers for new gas and for old gas released under the provisions of FERC's (Federal Energy Regulatory Commission) special marketing programs (SMPS). However, while certain users are enjoying or have enjoyed low cost gas made available through gas-to-gas competition, the market itself is not going anywhere. Year-to-year sales are down and show no real prospect of any improvement in 1986. The economy, which is geared to conservation and energy efficiency, is without expectations for significant gains this year and will not use more gas simply because it is cheaper.

Despite technical advances to reduce air pollution emissions, motor vehicles still account for 30 to 70% emissions of all urban air pollutants. The Clean Air Act Amendments of 1990 require 100 cities in the United States to reduce the amount of their smog within 5 to 15 years. Hence, auto emissions, the major cause of smog, must be reduced 30 to 60% by 1998. Naturalgas con be combusted with less pollutant emissions. Adsorbed naturalgas (ANG) uses adsorbents and operates with a low storage pressure which results in lower capital costs and maintenance. This paper describes the production of an activated carbon adsorbent produced from an Illinois coal for ANG.

Concerns over air quality and greenhouse gas emissions have prompted discussion as well as action on alternative fuels and energy efficiency. Naturalgas and naturalgas derived fuels and fuel additives are prime alternative fuel candidates for the transportation sector. In this study, we reexamine and add to past work on energy efficiency and greenhouse gas emissions of naturalgas fuels for transportation (DeLuchi 1991, Santini et a. 1989, Ho and Renner 1990, Unnasch et al. 1989). We add to past work by looking at Methyl tertiary butyl ether (from naturalgas and butane component of naturalgas), alkylate (from naturalgas butanes), and gasoline from naturalgas. We also reexamine compressed naturalgas, liquified naturalgas, liquified petroleum gas, and methanol based on our analysis of vehicle efficiency potential. We compare the results against nonoxygenated gasoline.

Concerns over air quality and greenhouse gas emissions have prompted discussion as well as action on alternative fuels and energy efficiency. Naturalgas and naturalgas derived fuels and fuel additives are prime alternative fuel candidates for the transportation sector. In this study, we reexamine and add to past work on energy efficiency and greenhouse gas emissions of naturalgas fuels for transportation (DeLuchi 1991, Santini et a. 1989, Ho and Renner 1990, Unnasch et al. 1989). We add to past work by looking at Methyl tertiary butyl ether (from naturalgas and butane component of naturalgas), alkylate (from naturalgas butanes), and gasoline from naturalgas. We also reexamine compressed naturalgas, liquified naturalgas, liquified petroleum gas, and methanol based on our analysis of vehicle efficiency potential. We compare the results against nonoxygenated gasoline.

Praxair, in conjunction with the Los Alamos National Laboratory, is developing a new technology, thermoacoustic heat engines and refrigerators, for liquefaction of naturalgas. This is the only technology capable of producing refrigeration power at cryogenic temperatures with no moving parts. A prototype, with a projected naturalgas liquefaction capacity of 500 gallons/day, has been built and tested. The power source is a naturalgas burner. Systems will be developed with liquefaction capacities up to 10,000 to 20,000 gallons per day. The technology, the development project, accomplishments and applications are discussed. In February 2001 Praxair, Inc. purchased the acoustic heat engine and refrigeration development program from Chart Industries. Chart (formerly Cryenco, which Chart purchased in 1997) and Los Alamos had been working on the technology development program since 1994. The purchase included assets and intellectual property rights for thermoacoustically driven orifice pulse tube refrigerators (TADOPTR), a new and revolutionary Thermoacoustic Stirling Heat Engine (TASHE) technology, aspects of Orifice Pulse Tube Refrigeration (OPTR) and linear motor compressors as OPTR drivers. Praxair, in cooperation with Los Alamos National Laboratory (LANL), the licensor of the TADOPTR and TASHE patents, is continuing the development of TASHE-OPTR naturalgas powered, naturalgas liquefiers. The liquefaction of naturalgas, which occurs at -161 C (-259 F) at atmospheric pressure, has previously required rather sophisticated refrigeration machinery. The 1990 TADOPTR invention by Drs. Greg Swift (LANL) and Ray Radebaugh (NIST) demonstrated the first technology to produce cryogenic refrigeration with no moving parts. Thermoacoustic engines and refrigerators use acoustic phenomena to produce refrigeration from heat. The basic driver and refrigerator consist of nothing more than helium-filled heat exchangers and pipes, made of common materials, without exacting tolerances

Gas Technology Institute (GTI) is conducting this research program whose objective is to develop gas/liquid membranes for naturalgas upgrading to assist DOE in achieving their goal of developing novel methods of upgrading low quality naturalgas to meet pipeline specifications. Kvaerner Process Systems (KPS) and W. L. Gore & Associates (GORE) gas/liquid membrane contactors are based on expanded polytetrafluoroethylene (ePTFE) membranes acting as the contacting barrier between the contaminated gas stream and the absorbing liquid. These resilient membranes provide much greater surface area for transfer than other tower internals, with packing densities five to ten times greater, resulting in equipment 50-70% smaller and lower weight for the same treating service. The scope of the research program is to (1) build and install a laboratory- and a field-scale gas/liquid membrane absorber; (2) operate the units with a low quality naturalgas feed stream for sufficient time to verify the simulation model of the contactors and to project membrane life in this severe service; and (3) conducted an economic evaluation, based on the data, to quantify the impact of the technology. Chevron, one of the major producers of naturalgas, has offered to host the test at a gas treating plant. KPS will use their position as a recognized leader in the construction of commercial amine plants for building the unit along with GORE providing the membranes. GTI will provide operator and data collection support during lab- and field-testing to assure proper analytical procedures are used. Kvaerner and GTI will perform the final economic evaluation. GTI will provide project management and be responsible for reporting and interactions with DOE on this project. Efforts this quarter have concentrated on field site selection. ChevronTexaco has nominated their Headlee Gas Plant in Odessa, TX for a commercial-scale dehydration test. Design and cost estimation for this new site are underway. A Haz

Gas Technology Institute (GTI) is conducting this research program whose objective is to develop gas/liquid membranes for naturalgas upgrading to assist DOE in achieving their goal of developing novel methods of upgrading low quality naturalgas to meet pipeline specifications. Kvaerner Process Systems (KPS) and W. L. Gore & Associates (GORE) gas/liquid membrane contactors are based on expanded polytetrafluoroethylene (ePTFE) membranes acting as the contacting barrier between the contaminated gas stream and the absorbing liquid. These resilient membranes provide much greater surface area for transfer than other tower internals, with packing densities five to ten times greater, resulting in equipment 50-70% smaller and lower weight for the same treating service. The scope of the research program is to (1) build and install a laboratory- and a field-scale gas/liquid membrane absorber; (2) operate the units with a low quality naturalgas feed stream for sufficient time to verify the simulation model of the contactors and to project membrane life in this severe service; and (3) conducted an economic evaluation, based on the data, to quantify the impact of the technology. Chevron, one of the major producers of naturalgas, has offered to host the test at a gas treating plant. KPS will use their position as a recognized leader in the construction of commercial amine plants for building the unit along with GORE providing the membranes. GTI will provide operator and data collection support during lab- and field-testing to assure proper analytical procedures are used. Kvaerner and GTI will perform the final economic evaluation. GTI will provide project management and be responsible for reporting and interactions with DOE on this project. Efforts this quarter have concentrated on field site selection. ChevronTexaco has nominated their Headlee Gas Plant in Odessa, TX for a commercial-scale dehydration test. Design and cost estimation for this new site are underway. Potting

Even though the possibility of decontrol of naturalgas prices is being discussed, applications under the NaturalGas Policy Act of 1978 continue to flood the Texas Railroad Commission. As of mid-March, 33,965 applications had been filed with the TRC seeking ceiling price designations under the Act. During the first part of the year, the commission sponsored seminars in different parts of the state to explain the provisions of the Act and the commission's procedures in handling applications filed under the NGPA. Title 1 of the NGPA contains the wellhead pricing provisions. Eight major categories of domestically-produced gas with certain statutory maximum price levels are applied to all first sales. In Texas the TRC has jurisdiction over 4 of these categories: Section 102 - new naturalgas; Section 103 - new, onshore production naturalgas; Section 107 - high-cost naturalgas; and Section 108 - stripper well naturalgas. The Federal Energy Regulatory Commission in Washington has jurisdiction over the other categories which include: Section 104 - sales of naturalgas dedicated to interstate commerce; Section 105 - sales under existing intrastate contracts; Section 106 - sales under roll-over contracts; and Section 109 - other categories.

Pipeline safety in the United States has increased in recent decades, but incidents involving naturalgas pipelines still cause an average of 17 fatalities and $133 M in property damage annually. Naturalgas leaks are also the largest anthropogenic source of the greenhouse gas methane (CH4) in the U.S. To reduce pipeline leakage and increase consumer safety, we deployed a Picarro G2301 Cavity Ring-Down Spectrometer in a car, mapping 5893 naturalgas leaks (2.5 to 88.6 ppm CH4) across 1500 road miles of Washington, DC. The δ(13)C-isotopic signatures of the methane (-38.2‰ ± 3.9‰ s.d.) and ethane (-36.5 ± 1.1 s.d.) and the CH4:C2H6 ratios (25.5 ± 8.9 s.d.) closely matched the pipeline gas (-39.0‰ and -36.2‰ for methane and ethane; 19.0 for CH4/C2H6). Emissions from four street leaks ranged from 9200 to 38,200 L CH4 day(-1) each, comparable to naturalgas used by 1.7 to 7.0 homes, respectively. At 19 tested locations, 12 potentially explosive (Grade 1) methane concentrations of 50,000 to 500,000 ppm were detected in manholes. Financial incentives and targeted programs among companies, public utility commissions, and scientists to reduce leaks and replace old cast-iron pipes will improve consumer safety and air quality, save money, and lower greenhouse gas emissions. PMID:24432903

The past three years, Mitchell Energy and Development Corp. has undergone a massive restructuring that has changed the face of one of the nation`s largest and best-known naturalgas/naturalgas liquids companies. Facing a rapidly changing industry that frequently has been stung by volatile swings in energy markets, management of the independent company, founded by George Mitchell in 1946, sold off $300 million in non-core assets; reduced its long-term debt by $400 million; instituted a hiring freeze and reduced its workforce by a third, from 2,900 to 1,950, over the last three years. Mitchell negotiated a buyout of its hugely profitable North Texas gas sales contract with NaturalGas Pipeline Company of America as a means of easing its transition to a market-sensitive price environment and reducing its debt. Mitchell also took operational control. Finally, Mitchell has left the real estate business, culminating July 31 with the sale of its real estate subsidiary, The Woodlands Corporation, for $543 million ($460 million net after-tax), further reducing its workforce to 1,100. On Aug. 18, the company said it will use the proceeds to repurchase common stock, retire another $200 million of public debt, make asset niche energy acquisitions and increase capital spending for existing programs. The result is a renewed focus on its exploration and production and gas gathering, processing and marketing businesses.

The paper reviews the technology of the Fischer-Tropsch synthesis used in the Sasal plant in South Africa. It discusses environmental aspects and economics of new FT facilities for the production of diesel fuels. Several projects are briefly described which use this technology for naturalgas conversion.

A new methodology is implemented with the monthly naturalgas production estimates from the EIA-914 survey this month. The estimates, to be released April 29, 2010, include revisions for all of 2009. The fundamental changes in the new process include the timeliness of the historical data used for estimation and the frequency of sample updates, both of which are improved.

This document provides information on the supply and disposition of naturalgas to a wide audience including industry, consumers, Federal and State agencies, and educational institutions. This report, Volume 2, presents historical data for the Nation from 1930 to 1992, and by State from 1967 to 1992. The Supplement of this report presents profiles of selected companies.

Approximately 600 citations concerning safety of liquefied naturalgas and liquid methane are presented. Each entry includes the title, author, abstract, source, description of figures, key references, and major descriptors for retrieving the document. An author index is provided as well as an index of descriptors.

This study describes the Mexican naturalgas industry as it exists today and the factors that have shaped the evolution of the industry in the past or that are expected to influence its progress; it also projects production and use of naturalgas and estimates the market for exports of naturalgas from the United States to Mexico. The study looks ahead to two periods, a near term (1993--1995) and an intermediate term (1996--2000). The bases for estimates under two scenarios are described. Under the conservative scenario, exports of naturalgas from the United States would decrease from the 1992 level of 250 million cubic feet per day (MMCF/d), would return to that level by 1995, and would reach about 980 MMCF/D by 2000. Under the more optimistic scenario, exports would decrease in 1993 and would recover and rise to about 360 MMCF/D in 1995 and to 1,920 MMCF/D in 2000.

This article contains a foldout entitled NaturalGas and the Environment for use in helping students become more aware of the relationships that exist between humans and the environment. Suggestions for classroom integration of this subject into your curriculum are also provided. (ZWH)

In processing naturalgas liquids, significant contamination occurs with liquid dispersions and emulsions. Naturalgas liquids (NGL) and liquid petroleum gas (LPG) streams are treated with caustic to remove residual organic sulfur compounds such as mercaptans and with amines to remove hydrogen sulfide. In both cases a liquid/liquid contactor is used. Significant amounts of the caustic or amine can be carried over into the product stream in process units that are running at rates above design capacity, are treating high sulfur feed stocks, or have other operational problems. The carried over liquid results in off-spec products, excessive loses of caustic or amine, and can cause operating problems in downstream processes. In addition, water is a significant contaminant which can cause LPG and natural gasoline to be off-specification. This paper discusses a new technique for separating very stable liquid dispersions of caustic, amine, or water from naturalgas liquids using liquid/liquid cartridge coalescers constructed with specially formulated polymer and fluoropolymer medium with enhanced surface properties. In addition, factors influencing the coalescer mechanism will be discussed including interfacial tension, concentration of surface active compounds, steric repulsion, and electrostatic charge affects. Results from field tests, operating data from commercial installations, and economic benefits will also be presented.

Building upon the partitioning of the Greater Green River Basin (GGRB) that was conducted last quarter, the goal of the work this quarter has been to conclude evaluation of the Stratos well and the prototypical Green River Deep partition, and perform the fill resource evaluation of the Upper Cretaceous tight gas play, with the goal of defining target areas of enhanced natural fracturing. The work plan for the quarter of November 1-December 31, 1998 comprised four tasks: (1) Evaluation of the Green River Deep partition and the Stratos well and examination of potential opportunity for expanding the use of E and P technology to low permeability, naturally fractured gas reservoirs, (2) Gas field studies, and (3) Resource analysis of the balance of the partitions.

LDEF (Postflight), AO175 : Evaluation of Long-Duration Exposure to the Natural Space Environment on Graphite-Polyimide and Graphite-Epoxy Mechanical Properties, Tray A07 The postflight photograph was taken in the Operations and Control (O&C) facility after the LDEF had been transferred from the KSC Payload Transporter to the LDEF Assembly and Transport System (LATS) and shows more detail than the flight photograph. The areas on the aluminum mounting strips where the coating has been scraped and/or abraided can be seen in greater detail under the better lighting conditions. The coating color remains essentially the same. The white paint dots on the tray clampblocks have changed little from the orginal color. PMR-15 Graphite-Polyimide Panel (precured) - The PMR-15 graphite-polyimide laminated panel (T40T30060-009) postflight photograph provides more detail than the flight photograph. The geometric pattern seen on the flight photograph is not visible, however, the horizontal lines, cracks and/or crazing, observed previously are better defined. A gray haze or dust appears to cover the gray/brown panel surface. The yellow colored identification numbers seem to be a little lighter than in the flight photograph but the white marking in the upper left corner do not appear to have changed. Scratch marks/abrasions on the lower left edge of panel were on prelaunch photographs. F-178/T300 Graphite-Polyimide Panel (cocured) - The 178/T300 graphite-polyimide panel (T40T30060-005) seems to have changed in color from the light gray in the flight photograph to a brownish gray. The yellow identification numbers seem lighter while the white marking in the upper left corner appear brighter. The fine horizontal lines, cracks and/or crazing, are still visible on the panel surface. F178/T300 Graphite-Polyimide Panel (precured) - The 178/T300 graphite-polyimide laminated panel (T40T30060-001) seems to have changed to a brownish gray from the light gray color seen in the flight photograph

Multivariable constraint control (MCS) has a very beneficial and profitable impact on the operation of naturalgas plants. The applications described operate completely within a distributed control system (DCS) or programmable logic controllers (PLCs). That makes MCS accessible to almost all gas plant operators. The technology's relative ease of use, low maintenance effort and software sensor,'' make it possible to operate these control applications without increasing technical support staff. MCS improves not only profitability but also regulatory compliance of gas plants. It has been applied to fractionation units, cryogenic units, amine treaters, sulfur recovery units and utilities. The application typically pay for the cost of software and engineering in less than one month. If a DCS is installed within such a project the advanced control applications can generate a payout in less than one year. In the case here (an application on the deethanizers of a 500 MMscfd gas plant) product revenue increased by over $2 million/yr.

A fueling facility and method for dispensing liquid naturalgas (LNG), compressed naturalgas (CNG) or both on-demand. The fueling facility may include a source of LNG, such as cryogenic storage vessel. A low volume high pressure pump is coupled to the source of LNG to produce a stream of pressurized LNG. The stream of pressurized LNG may be selectively directed through an LNG flow path or to a CNG flow path which includes a vaporizer configured to produce CNG from the pressurized LNG. A portion of the CNG may be drawn from the CNG flow path and introduced into the CNG flow path to control the temperature of LNG flowing therethrough. Similarly, a portion of the LNG may be drawn from the LNG flow path and introduced into the CNG flow path to control the temperature of CNG flowing therethrough.

This report evaluates three major legislative proposals: accelerated decontrol of both old and new wellhead prices as proposed by the Reagan administration (S.615, H.R. 1760); imposition of new naturalgas price controls at lower levels as proposed by Congressman Gephardt (H.R. 2154); and conversion of interstate gas pipelines to common carriage as proposed by Senators Dixon and Percy and by Congressman Corcoran (S. 1119, H.R. 2565). The reference or base case scenario used in the evaluation is a continuation of the NaturalGas Policy Act of 1978 (NGPA) with no legislative modifications. First, projections of wellhead and burner-tip naturalgas prices are presented for the period 1983-1990, and then consumer benefits under the different scenarios are estimated. All projections presented assume that legislation takes effect as of January 1, 1983 and that normal weather patterns are experienced. All prices identified in the report are given in 1982 dollars unless otherwise indicated. 5 figs., 1 tab.

This paper deals with the use of membranes for hydrocarbon dewpointing and dehydration of naturalgas. Based on experience gained from membrane applications in separating organic vapors from off-gas and process streams, as well as the dehydration of compressed air, membranes have been developed and tested for use in high pressure applications. Membranes and membrane modules have been modified to withstand the high operating pressure. Calculation programs were developed to understand the separation performance and to provide the necessary information for optimizing membrane design. A real challenge was the introduction of the vacuum mode dehydration operation in order to achieve the highest possible dewpoint reduction with minimum methane loss. PMID:12783826

In March, work continued on characterizing probabilities for determining natural fracturing associated with the GGRB for the Upper Cretaceous tight gas plays. Structural complexity, based on potential field data and remote sensing data was completed. A resource estimate for the Frontier and Mesa Verde play was also completed. Further, work was also conducted to determine threshold economics for the play based on limited current production in the plays in the Wamsutter Ridge area. These analyses culminated in a presentation at FETC on 24 March 1999 where quantified natural fracture domains, mapped on a partition basis, which establish ''sweet spot'' probability for natural fracturing, were reviewed. That presentation is reproduced here as Appendix 1. The work plan for the quarter of January 1, 1999--March 31, 1999 comprised five tasks: (1) Evaluation of the GGRB partitions for structural complexity that can be associated with natural fractures, (2) Continued resource analysis of the balance of the partitions to determine areas with higher relative gas richness, (3) Gas field studies, (4) Threshold resource economics to determine which partitions would be the most prospective, and (5) Examination of the area around the Table Rock 4H well.

The focus of work performed by University of British Columbia researchers was on high-pressure (late cycle) injection of NG ignited by a pilot diesel-liquid injection(diesel/gas combustion). This was compared to the case of 100% liquid diesel (baseline diesel) fueling at the same load and speed. In typical direct-injected and conventionally fueled diesel engines, fuel is injected a few degrees before the end of the compression stroke into 750--900 K air in which it vaporizes, mixed with air, and auto ignites less than 2 ms after injection begins. The objectives of the researchers` work were to investigate the ignition delay and combustion duration of diesel/gas combustion by observing diesel and diesel/gas ignition sites and flame structure; determining ignition delay and combustion duration with pilot-diesel and naturalgas injections; determining whether the pilot liquid flame is substantially influenced by the gas injection; and considering whether pilot-diesel/gas combustion is dominated by premixed or diffusion combustion.

This report provides information on the total reserves, production, and deliverability capabilities of the 86 interstate pipeline companies required to file the Federal Energy Regulatory Commission (FERC) Form 15, Interstate Pipeline's Annual Report of Gas Supply. Total dedicated domestic gas reserves, owned by or under contract to the interstate pipeline companies, decreased in 1983 by 4.2 trillion cubic feet (Tcf), or 4.3%, from 98.7 Tcf at the beginning of the year to 94.5 Tcf at the end of the year. A 5-year tabulation shows that dedicated domestic gas reserves increased slightly from 94.0 Tcf at the beginning of 1979 to 94.5 Tcf at the end of 1983, an increase of 0.5 Tcf, or 0.5%. Total gas purchased and produced from the dedicated domestic gas reserves in 1983 was 9.5 Tcf, down 13.1% from the 10.9 Tcf reported in the preceding year. The 1983 ratio of total dedicated domestic reserves to production was 10.0, significantly above the 9.0 ratio reported for 1982. Net revisions to dedicated domestic gas reserves during 1983 are calculated at -0.5 Tcf, as compared to 1.4 Tcf in 1982. Total interstate reserve additions during 1983 are reported to be 5.8 Tcf, compared to additions of 9.9 Tcf in 1982. Total naturalgas imported by interstate pipeline companies from two foreign sources, Canada and Mexico, was 0.8 Tcf, 7.4% of the total gas produced and purchased in 1983. Imports of LNG from Algeria totaled only 0.09 Tcf. Total deliveries are projected to decline from 12.9 Tcf in 1984 to 7.1 Tcf by 1988. This decline is driven by the projected decline in domestic reserve deliverability. Deliveries from foreign and other sources are expected to remain relatively constant over the 5-year period. 8 figures, 18 tables.

The objectives of the Infield Growth/Secondary NaturalGas Recovery project have been: To establish how depositional and diagenetic heterogeneities in reservoirs of conventional permeability cause reservoir compartmentalization and, hence, incomplete recovery of naturalgas. To document practical, field-oriented examples of reserve growth from fluvial and deltaic sandstones of the Texas gulf coast basin and to use these gas reservoirs as a natural laboratory for developing concepts and testing applications of both tools and techniques to find secondary gas. To demonstrate how the integration of geology, reservoir engineering, geophysics, and well log analysis/petrophysics leads to strategic recompletion and well placement opportunities for reserve growth in mature fields. To transfer project results to naturalgas producers, not just as field case studies, but as conceptual models of how heterogeneities determine naturalgas flow and how to recognize the geologic and engineering clues that operators can use in a cost-effective manner to identify secondary gas. Accomplishments are presented for: reservoir characterization; integrated formation evaluation and engineering testing; compartmented reservoir simulator; and reservoir geophysics.

The primary objective of the Infield Reserve Growth/Secondary NaturalGas Recovery (SGR) project is to develop, test, and verify technologies and methodologies with near- to midterm potential for maximizing the recovery of natural gasfrom conventional reservoirs in known fields. Additional technical and technology transfer objectives of the SGR project include: To establish how depositional and diagenetic heterogeneities in reservoirs of conventional permeability cause reservoir compartmentalization and, hence, incomplete recovery of naturalgas. To document examples of reserve growth occurrence and potential from fluvial and deltaic sandstones of the Texas gulf coast basin as a natural laboratory for developing concepts and testing applications to find secondary gas. To demonstrate how the integration of geology, reservoir engineering, geophysics, and well log analysis/petrophysics leads to strategic recompletion and well placement opportunities for reserve growth in mature fields. To transfer project results to a wide array of naturalgas producers, not just as field case studies, but as conceptual models of how heterogeneities determine naturalgas flow units and how to recognize the geologic and engineering clues that operators can use in a cost-effective manner to identify incremental, or secondary, gas.

The Pennsylvania State University, under contract to the U.S. Department of Energy (DOE), National Energy Technology Laboratory (NETL), established a national industry-driven Stripper Well Consortium (SWC) that is focused on improving the production performance of domestic petroleum and/or naturalgas stripper wells. The SWC represents a partnership between U.S. petroleum and naturalgas producers, trade associations, state funding agencies, academia, and the NETL. This document serves as the twelfth quarterly technical progress report for the SWC. Key activities for this reporting period included: (1) Drafting and releasing the 2007 Request for Proposals; (2) Securing a meeting facility, scheduling and drafting plans for the 2007 Spring Proposal Meeting; (3) Conducting elections and announcing representatives for the four 2007-2008 Executive Council seats; (4) 2005 Final Project Reports; (5) Personal Digital Assistant Workshops scheduled; and (6) Communications and outreach.

In 1990 Western Resources Inc. (WRI) identified the need for additional naturalgas storage capacity for its intrastate naturalgas system operated in the state of Kansas. Western Resources primary need was identified as peak day deliverability with annual storage balancing a secondary objective. Consequently, an underground bedded salt storage facility, Yaggy Storage Field, was developed and placed in operation in November 1993. The current working capacity of the new field is 2.1 BCF. Seventy individual caverns are in service on the 300 acre site. The caverns vary in size from 310,000 CF to 2,600,000 CF. Additional capacity can be added on the existing acreage by increasing the size of some of the smaller existing caverns by further solution mining and by development of an additional 30 potential well sites on the property.

The goal of the work this quarter has been to partition and high-grade the Greater Green River basin for exploration efforts in the Upper Cretaceous tight gas play and to initiate resource assessment of the basin. The work plan for the quarter of July 1-September 30, 1998 comprised three tasks: (1) Refining the exploration process for deep, naturally fractured gas reservoirs; (2) Partitioning of the basin based on structure and areas of overpressure; (3) Examination of the Kinney and Canyon Creek fields with respect to the Cretaceous tight gas play and initiation of the resource assessment of the Vermilion sub-basin partition (which contains these two fields); and (4) Initiation analysis of the Deep Green River Partition with respect to the Stratos well and assessment of the resource in the partition.

This chapter focuses upon the capabilities of the national naturalgas pipeline network, examining how it has expanded during this decade and how it may expand further over the coming years. It also looks at some of the costs of this expansion, including the environmental costs which may be extensive. Changes in the network as a result of recent regional market shifts are also discussed.

The purpose of this document is to familiarize the reader with the general configuration and operation of the naturalgas pipelines in California and to discuss potential LLNL contributions that would support the Partnership for the 21st Century collaboration. First, pipeline infrastructure will be reviewed. Then, recent pipeline events will be examined. Selected current pipeline industry research will be summarized. Finally, industry acronyms are listed for reference.

The Pennsylvania State University, under contract to the U.S. Department of Energy (DOE), National Energy Technology Laboratory (NETL) established a national industry-driven Stripper Well Consortium (SWC) that is focused on improving the production performance of domestic petroleum and/or naturalgas stripper wells. The consortium creates a partnership with the U.S. petroleum and naturalgas producers, trade associations, state funding agencies, academia, and the National Energy Technology Laboratory. This report serves as the tenth quarterly technical progress report for the SWC. Key activities for this reporting period include: {lg_bullet} 2004 SWC Final Project Reports distribution; {lg_bullet} Exhibit and present at the Midcontinent Oil and Gas Prospect Fair, Great Bend, KS, September 12, 2006; {lg_bullet} Participate and showcase current and past projects at the 2006 Oklahoma Oil and Gas Trade Expo, Oklahoma City, OK, October 26, 2006; {lg_bullet} Finalize agenda and identify exhibitors for the northeastern US, Fall SWC Technical Transfer Workshop, Pittsburghhh, PA, November 9, 2006; {lg_bullet} Continue distribution of the public broadcast documentary, ''Independent Oil: Rediscovering American's Forgotten Wells''; {lg_bullet} Communications/outreach; and {lg_bullet} New members update.

This Research and Development Subcontract sought to find economic, technical and policy links between methane recovery at landfill and wastewater treatment sites in New York and Maryland, and ways to use that methane as an alternative fuel--compressed naturalgas (CNG) or liquid naturalgas (LNG) -- in centrally fueled Alternative Fueled Vehicles (AFVs).

World natural-gas consumption quadrupled in the 30 years from 1966 to 1996, and naturalgas now provides 22% of the total world energy demand. The security of natural-gas supply is paramount and rests with the suppliers and the consumers. This paper gives an overview of world natural-gas supply and demand and examines the main supply problems. The most important nonpredictable variables in natural-gas supply are worldwide gas price and political stability, particularly in regions with high reserves. Other important considerations are the cost of development/processing and the transport of naturalgas to market, which can be difficult to maintain if pipelines pass through areas of political instability. Another problem is that many countries lack the infrastructure and capital for effective development of their natural-gas industry. Unlike oil, the cost of transportation of naturalgas is very high, and, surprisingly, only approximately 16% of the total world production currently is traded internationally.

The project objective is to demonstrate the viability of HCNG fuel (30 to 50% hydrogen by volume and the remainder naturalgas) to reduce emissions from light-duty on-road vehicles with no loss in performance or efficiency. The City of Las Vegas has an interest in alternative fuels and already has an existing hydrogen refueling station. Collier Technologies Inc (CT) supplied the latest design retrofit kits capable of converting nine compressed naturalgas (CNG) fueled, light-duty vehicles powered by the Ford 5.4L Triton engine. CT installed the kits on the first two vehicles in Las Vegas, trained personnel at the City of Las Vegas (the City) to perform the additional seven retrofits, and developed materials for allowing other entities to perform these retrofits as well. These vehicles were used in normal service by the City while driver impressions, reliability, fuel efficiency and emissions were documented for a minimum of one year after conversion. This project has shown the efficacy of operating vehicles originally designed to operate on compressed naturalgas with HCNG fuel incorporating large quantities of exhaust gas recirculation (EGR). There were no safety issues experienced with these vehicles. The only maintenance issue in the project was some rough idling due to problems with the EGR valve and piping parts. Once the rough idling was corrected no further maintenance issues with these vehicles were experienced. Fuel economy data showed no significant changes after conversion even with the added power provided by the superchargers that were part of the conversions. Driver feedback for the conversions was very favorable. The additional power provided by the HCNG vehicles was greatly appreciated, especially in traffic. The drivability of the HCNG vehicles was considered to be superior by the drivers. Most of the converted vehicles showed zero oxides of nitrogen throughout the life of the project using the State of Nevada emissions station.

... conservation of natural resources-naturalgas. 2.78 Section 2.78 Conservation of Power and Water Resources... INTERPRETATIONS Statements of General Policy and Interpretations Under the NaturalGas Act § 2.78 Utilization and conservation of natural resources—naturalgas. (a)(1) The national interests in the development and...

... conservation of natural resources-naturalgas. 2.78 Section 2.78 Conservation of Power and Water Resources... INTERPRETATIONS Statements of General Policy and Interpretations Under the NaturalGas Act § 2.78 Utilization and conservation of natural resources—naturalgas. (a)(1) The national interests in the development and...

... conservation of natural resources-naturalgas. 2.78 Section 2.78 Conservation of Power and Water Resources... INTERPRETATIONS Statements of General Policy and Interpretations Under the NaturalGas Act § 2.78 Utilization and conservation of natural resources—naturalgas. (a)(1) The national interests in the development and...

... conservation of natural resources-naturalgas. 2.78 Section 2.78 Conservation of Power and Water Resources... INTERPRETATIONS Statements of General Policy and Interpretations Under the NaturalGas Act § 2.78 Utilization and conservation of natural resources—naturalgas. (a)(1) The national interests in the development and...

... conservation of natural resources-naturalgas. 2.78 Section 2.78 Conservation of Power and Water Resources... INTERPRETATIONS Statements of General Policy and Interpretations Under the NaturalGas Act § 2.78 Utilization and conservation of natural resources—naturalgas. (a)(1) The national interests in the development and...

The Chinese government has supported the development of the naturalgas industry since the sixth {open_quotes}Five-Year Plan{close_quotes} (1981-1985) by studying naturalgas and its origin, one of the key research projects in technology and science. This ongoing research has shown that natural gases in China are composed of three types: coal-type gas related to coal measures; high-temperature pyrolytic gas related to Paleozoic carbonates; and oil-type gas, which occurs in oil fields related to Cenozoic and Mesozoic lacustrine sediments. Each of these three types constitutes about one-third of the total observed reserves of naturalgas in China. Since 1990, we have proposed a new genetic theory of naturalgas multisource overlap and multistage continuity; a new biogenic-thermocatalytic transitional zone gas; and comprehensively identifying coal-type gas, which plays an important role in exploring for naturalgas.

The Pennsylvania State University, under contract to the U.S. Department of Energy (DOE), National Energy Technology Laboratory (NETL), established a national industry-driven Stripper Well Consortium (SWC) that is focused on improving the production performance of domestic petroleum and/or naturalgas stripper wells. The SWC represents a partnership between U.S. petroleum and naturalgas producers, trade associations, state funding agencies, academia, and the NETL. This document serves as the eleventh quarterly technical progress report for the SWC. Key activities for this reporting period included: (1) Organizing and hosting the Fall SWC Technology Transfer Workshop for the northeastern U.S., in Pittsburgh, PA, on November 9, 2006, and organizing and identifying projects to exhibit during the SWC/Gas Storage Technology Consortium (GSTC) joint reception on November 8, 2006; (2) Distributing a paper copy of the Texas Tech 2004 Final Report and a revised, complete compact disc of all 2004 final reports; (3) Invoicing current and potential members for FY2007; (4) Soliciting nominations for the 2007-2008 Executive Council seats; and (5) Communications and outreach.

Flex Fuel Polygeneration (FFPG) is the use of multiple primary energy sources for the production of multiple energy carriers to achieve increased market opportunities. FFPG allows for adjustments in energy supply to meet market fluctuations and increase resiliency to contingencies such as weather disruptions, technological changes, and variations in supply of energy resources. In this study a FFPG plant is examined that uses a combination of the primary energy sources naturalgas and renewable naturalgas (RNG) derived from MSW and livestock manure and converts them into energy carriers of electricity and fuels through anaerobic digestion (AD), Fischer-Tropsch synthesis (FTS), and gas turbine cycles. Previous techno-economic analyses of conventional energy production plants are combined to obtain equipment and operating costs, and then the 20-year NPVs of the FFPG plant designs are evaluated by static and stochastic simulations. The effects of changing operating parameters are investigated, as well as the number of anaerobic digestion plants on the 20-year NPV of the FTS and FFPG systems.

Direct knowledge of the rates of gas exchange in lakes and the ocean is based almost entirely on measurements of the isotopes /sup 14/C, /sup 222/Rn and /sup 3/He. The distribution of natural radiocarbon has yielded the average rate of CO/sub 2/ exchange for the ocean and for several closed basin lakes. That of bomb produced radiocarbon has been used in the same systems. The /sup 222/Rn to /sup 226/Ra ratio in open ocean surface water has been used to give local short term gas exchange rates. The radon method generally cannot be used in lakes, rivers, estuaries or shelf areas because of the input of radon from sediments. A few attempts have been made to use the excess /sup 3/He produced by decay of bomb produced tritium in lakes to give gas transfer rates. The uncertainty in the molecular diffusivity of helium and in the diffusivity dependence of the rate of gas transfer holds back the application of this method. A few attempts have been made to enrich the surface waters of small lakes with /sup 226/Ra and /sup 3/H in order to allow the use of the /sup 222/Rn and /sup 3/He methods. While these studies give broadly concordant results, many questions remain unanswered. The wind velocity dependence of gas exchange rate has yet to be established in field studies. The dependence of gas exchange rate on molecular diffusivity also remains in limbo. Finally, the degree of enhancement of CO/sub 2/ exchange through chemical reactions has been only partially explored. 49 references, 2 figures, 2 tables.

A new generation of the light-emitting diodes (LEDs) and photodiodes (PDs) was used recently to develop an open path non-dispersive infrared (NDIR) methane analyzer. The first open path detector prototype was constructed using LEDs for measurement and reference channels, accordingly, and first measurements for methane gas have been performed using optical paths of the order of several meters [3]. The naturalgas consists of several first alkanes, mainly methane, and it is important to have a possibility of measuring all of them. In the present work we report the results of NDIR measurements for propane-butane mixture and new measurements of methane using LEDs for measurement and reference channels at 2300 and 1700 nm wavelengths, accordingly. The necessity of the double beam scheme is demonstrated and obtained results for methane and propane-butane mixture are compared.

Energy from woody biomass could supplement renewable energy production towards the replacement of fossil fuels. A multi-stage process involving gasification of wood and then catalytic transformation of the producer gas to synthetic naturalgas (SNG) represents progress in this direction. SNG can be transported and distributed through the existing pipeline grid, which is advantageous from an economical point of view. Therefore, CO methanation is attracting a great deal of attention and much research effort is focusing on the understanding of the process steps and its further development. This short review summarizes recent efforts at Paul Scherrer Institute on the understanding of the reaction mechanism, the catalyst deactivation, and the development of catalytic materials with benign properties for CO methanation. PMID:26598405

Environmental Data Energy Technology Characterizations are publications which are intended to provide policy analysts and technical analysts with basic environmental data associated with key energy technologies. This publication provides backup documentation on naturalgas. The transformation of the energy in gas into a more useful form is described in this document in terms of major activity areas in the gas cycle; that is, in terms of activities which produce either an energy product or a fuel leading to the production of an energy product in a different form. The activities discussed in this document are exploration, extraction, purification, power-plants, storage and transportation of naturalgas. These activities represent both well-documented and non-documented activity areas. The former activities are characterized in terms of actual operating data with allowance for future modification where appropriate. Emissions are assumed to conform to environmental standards. The other activity areas examined are those like exploration and extraction, where reliance on engineering studies provided the data. The organization of the chapters in this volume is designed to support the tabular presentation in the summary. Each chapter begins with a brief description of the activity under consideration. The standard characteristics, size, availability, mode of functioning, and place in the fuel cycle are presented. Next, major legislative and/or technological factors influencing the commercial operation of the activity are offered. Discussions of resources consumed, residuals produced, and economics follow. To aid in comparing and linking the different activity areas, data for each area are normalized to 10/sup 12/ Btu of energy output from the activity.

Additions in 2008 and Projects through 2011. This report examines new naturalgas pipeline capacity added to the U.S. naturalgas pipeline system during 2008. In addition, it discusses and analyzes proposed naturalgas pipeline projects that may be developed between 2009 and 2011, and the market factors supporting these initiatives.

... Energy Regulatory Commission Corning NaturalGas Corporation; Notice of Application August 4, 2010. Take notice that on July 26, 2010, Corning NaturalGas Corporation (Corning), 330 W. William Street, Corning... NaturalGas Act (NGA) requesting the determination of a service area with which Corning may,...

... Energy Regulatory Commission Northern NaturalGas Company; Notice of Application June 16, 2010. Take notice that on June 2, 2010, Northern NaturalGas Company (Northern), 1111 South 103rd Street, Omaha... NaturalGas Act, for a certificate of public convenience and necessity authorizing the increase...

This special report looks at the current status of market centers/hubs in today's naturalgas marketplace, examining their role and their importance to naturalgas shippers, marketers, pipelines, and others involved in the transportation of naturalgas over the North American pipeline network.

The composition of working principle and calibration status of LNG (Liquefied NaturalGas) dispenser in China are introduced. According to the defect of weighing method in the calibration of LNG dispenser, LNG dispenser verification device has been researched. The verification device bases on the master meter method to verify LNG dispenser in the field. The experimental results of the device indicate it has steady performance, high accuracy level and flexible construction, and it reaches the international advanced level. Then LNG dispenser verification device will promote the development of LNG dispenser industry in China and to improve the technical level of LNG dispenser manufacture.

Given the extensive available resources of coal and, to a lesser extent, naturalgas, the challenge to access these resources in a way that balances growth and conservation in a responsible way, is a tough technological task. On the one hand there is the inadverterable and undesirable liberation of CO{sub 2} when carbon is used and on the other hand it is reasonable to assume that hydrocarbon liquids will, for the foreseeable future, remain the backbone of the supply of energy to automotive vehicles. It is therefore necessary that options for improved environmental performance of such fuels are developed and considered for application where the economics would permit it.

In connection with the construction of four major liquefied naturalgas (LNG) facilities in New York City, the New York City Fire Commissioner has asked NASA for assistance. It was decided that the Kennedy Space Center should develop a risk management system (RMS) for the use of the New York Fire Department (NYFD). The RMS provides for a published set of safety regulations by the NYFD. A description of the RMS is presented as an example of an application of aerospace technology to a civilian sector, namely LNG facilities.

Single-walled, jacketed aluminum tanks have been conceived for storing liquefied naturalgas (LNG) in LNG-fueled motor vehicles. Heretofore, doublewall steel tanks with vacuum between the inner and outer walls have been used for storing LNG. In comparison with the vacuum- insulated steel tanks, the jacketed aluminum tanks weigh less and can be manufactured at lower cost. Costs of using the jacketed aluminum tanks are further reduced in that there is no need for the vacuum pumps heretofore needed to maintain vacuum in the vacuum-insulated tanks.

The NaturalGas and Oil Technology Partnership expedites development and transfer of advanced technologies through technical interactions and collaborations between the national laboratories and the petroleum industry - majors, independents, service companies, and universities. The Partnership combines the expertise, equipment, facilities, and technologies of the Department of Energy`s national laboratories with those of the US petroleum industry. The laboratories utilize unique capabilities developed through energy and defense R&D including electronics, instrumentation, materials, computer hardware and software, engineering, systems analysis, physics, and expert systems. Industry contributes specialized knowledge and resources and prioritizes Partnership activities.

A storage tank is provided for storing liquefied naturalgas on, for example, a motor vehicle such as a bus or truck. The storage tank includes a metal liner vessel encapsulated by a resin-fiber composite layer. A foam insulating layer, including an outer protective layer of epoxy or of a truck liner material, covers the composite layer. A non-conducting protective coating may be painted on the vessel between the composite layer and the vessel so as to inhibit galvanic corrosion.

Liquefied naturalgas and hydrogen gasification process is suggested, in which vapor phase is generated by the decrease of internal energy of the liquid. Methane and hydrogen gasification processes have been numerically modeled. Flow rates of the methane and hydrogen through choke channel were defined. A satisfactory match between the modeled and experimental data for liquid nitrogen has been acquired. Technical suitability of the suggested process is proved. Based on the initial parameters of the cryogenic fluid, the amount of vapor phase is 5-20% of the flow rate.

An engineering research and design competition to develop and demonstrate dedicated naturalgas-powered light-duty trucks, the NaturalGas Vehicle (NGV) Challenge, was held June 6--11, 1191, in Oklahoma. Sponsored by the US Department of Energy (DOE), Energy, Mines, and Resources -- Canada (EMR), the Society of Automative Engineers (SAE), and General Motors Corporation (GM), the competition consisted of rigorous vehicle testing of exhaust emissions, fuel economy, performance parameters, and vehicle design. Using Sierra 2500 pickup trucks donated by GM, 24 teams of college and university engineers from the US and Canada participated in the event. A gasoline-powered control testing as a reference vehicle. This paper discusses the results of the event, summarizes the technologies employed, and makes observations on the state of naturalgas vehicle technology.

An engineering research and design competition to develop and demonstrate dedicated naturalgas-powered light-duty trucks, the NaturalGas Vehicle (NGV) Challenge, was held June 6--11, 1191, in Oklahoma. Sponsored by the US Department of Energy (DOE), Energy, Mines, and Resources -- Canada (EMR), the Society of Automative Engineers (SAE), and General Motors Corporation (GM), the competition consisted of rigorous vehicle testing of exhaust emissions, fuel economy, performance parameters, and vehicle design. Using Sierra 2500 pickup trucks donated by GM, 24 teams of college and university engineers from the US and Canada participated in the event. A gasoline-powered control testing as a reference vehicle. This paper discusses the results of the event, summarizes the technologies employed, and makes observations on the state of naturalgas vehicle technology.

An engineering research and design competition to develop and demonstrate dedicated naturalgas-powered light-duty trucks, the NaturalGas Vehicle (NGV) Challenge, was held June 6-11, 1991, in Oklahoma. Sponsored by the US Department of Energy (DOE), Energy, Mines, and Resources -- Canada (EMR), the Society of Automative Engineers (SAE), and General Motors Corporation (GM), the competition consisted of rigorous vehicle testing of exhaust emissions, fuel economy, performance parameters, and vehicle design. Using Sierra 2500 pickup trucks donated by GM, 24 teams of college and university engineers from the US and Canada participated in the event. A gasoline-powered control was included in the performance testing as a reference vehicle. This paper discusses the results of the event, summarizes the technologies employed, and makes observations on the state of naturalgas vehicle technology.

It is suspected that most shallow reservoirs of naturalgas vent to the surface to some degree. This seeping may be through diffusion of dissolved gas or by a flow of gas bubbles which entrain interstitial water during the rise through the sediments to the surface. Methane bubbles dissolved other gases, notably hydrogen sulphide and carbon dioxide, during their ascent. Under suitable temperature-pressure conditions gas hydrates may be formed close to or at the seabed Black suphide-rich sediments and mats of sulphur oxidizing bacteria are frequently observed close to the sediments surface at seep sites, including a sharp oxic/anoxic boundary. Animal species associated with these gas seeps include both species which obtain nutrition from symbiotic methane-oxidizing bacteria and species with symbolic sulphur-oxidizing bacteria. It is suspected that at some microseepage an enhanced biomass of meiofauna and macrofauna is supported by a food chain based on free-living and symbiotic sulphur-oxidizing and methane-oxidizing bacteria. The most common seep-related features of sea floor topography are local depressions including pockmark craters. Winnowing of the sediment during their creation leads to an accumulation of larger detritis in the depressions. Where the deprssions overlies salt diapirs they may be filled with hypersaline solutions. In some areas dome-shaped features are associated with seepage and these may be colonized by coral reefs. Other reefs, "hard-grounds", columnar and disc-shaped protrusions, all formed of carbonate-cemented sediments, are common on the sea floor in seep areas. Much of the carbonate appears to be derived from carbon dioxide formed as a result of methane oxidation. The resulting hard-bottoms on the sea floor are often colonized by species not found on the neighboring soft-bottoms. As a result seep areas may be characterized by the presence of a rich epifauna.

In 1996 and 1997, the naturalgas industry was intensely focused on the debate surrounding proposed new rules governing the gathering and transportation of naturalgas in Texas by the Railroad Commission. This paper reviews that debate and several other regulatory issues that could impact the naturalgas and gas processing industries over the next few years. In addition to the review of the Code of Conduct, this paper focuses on results of the informal complaint process, implementation of new legislation requiring the approval of construction of sour gas pipelines and several other naturalgas related issues.

The overall objective of this research project is to develop a catalytic process to convert naturalgas to liquid transportation fuels. The process, called the HSM (Hydrogen Sulfide-Methane) Process, consists of two steps that each utilize a catalyst and sulfur-containing intermediates: (1) converting naturalgas to CS{sub 2} and (2) converting CS{sub 2} to gasoline range liquids. Catalysts have been found that convert methane to carbon disulfide in yields up to 98%. This exceeds the target of 40% yields for the first step. The best rate for CS{sub 2} formation was 132 g CS{sub 2}/kg-cat-h. The best rate for hydrogen production is 220 L H{sub 2} /kg-cat-h. A preliminary economic study shows that in a refinery application hydrogen made by the HSM technology would cost $0.25-R1.00/1000 SCF. Experimental data will be generated to facilitate evaluation of the overall commercial viability of the process.

Industrial baking is one of the largest naturalgas consumers in the food industry. In 1985, bread, rolls, cookies, and crackers accounted for over 82 percent of all baked goods production. Bread accounting for 46 percent of all production. The baking industry consumed approximately 16 trillion Btu in 1985. About 93 percent was naturalgas, while distillate fuel oil accounted for seven percent, and electricity accounted for much less than one percent. The three main types of baking ovens are the single lap, tunnel, and Lanham ovens. In the single lap oven, trays carry the product back and forth through the baking chamber once. The single lap oven is the most common type of oven and is popular due to its long horizontal runs, extensive steam zone, and simple construction. The tunnel oven is slightly more efficient and more expensive that the single lap oven. IN the tunnel oven, the hearth is a motorized conveyor which passes in a straight line through a series of heating zones, with loading and unloading occurring at opposite ends of the oven. The advantages of the tunnel oven include flexibility with respect to pan size and simple, accurate top and bottom heat control. The tunnel oven is used exclusively in the cookie and cracker baking, with the product being deposited directly on the oven band. The most recently developed type of oven is the Lanham oven. The Lanham oven is the most efficient type of oven, with a per pound energy consumption approaching the practical minimum for baking bread. Between one--half and two--thirds of all new industrial baking ovens are Lanham ovens. In the Lanham oven, the product enters the oven near the top of the chamber, spirals down through a series of heating zones, and exits near the bottom of the oven. The oven is gas--fired directly by ribbon burners. 31 refs.

Presents a two-dimensional unsteady model of heat transfer in terms of condensation of naturalgas at low temperatures. Performed calculations of the process heat and mass transfer of liquefied naturalgas (LNG) storage tanks of cylindrical shape. The influence of model parameters on the nature of heat transfer. Defined temperature regimes eliminate evaporation by cooling liquefied naturalgas. The obtained dependence of the mass flow rate of vapor condensation gas temperature. Identified the possibility of regulating the process of "cooling down" liquefied naturalgas in terms of its partial evaporation with low cost energy.

This paper illustrates a key lesson related to most uses of long-range climate forecast information, namely that effective weather-related decision-making requires understanding and integration of weather information with other, often complex factors. Northern Illinois University's heating plant manager and staff meteorologist, along with a group of meteorology students, worked together to assess different types of available information that could be used in an autumn naturalgas purchasing decision. Weather information assessed included the impact of ENSO events on winters in northern Illinois and the Climate Prediction Center's (CPC) long-range climate outlooks. Non-weather factors, such as the cost and available supplies of naturalgas prior to the heating season, contribute to the complexity of the naturalgas purchase decision. A decision tree was developed and it incorporated three parts: (a) naturalgas supply levels, (b) the CPC long-lead climate outlooks for the region, and (c) an ENSO model developed for DeKalb. The results were used to decide in autumn whether to lock in a price or ride the market each winter. The decision tree was tested for the period 1995-99, and returned a cost-effective decision in three of the four winters.

The work plan for October 1, 1997 to September 30, 1998 consisted of investigation of a number of topical areas. These topical areas were reported in four quarterly status reports, which were submitted to DOE earlier. These topical areas are reviewed in this volume. The topical areas covered during the year were: (1) Development of preliminary tests of a production method for determining areas of natural fracturing. Advanced Resources has demonstrated that such a relationship exists in the southern Piceance basin tight gas play. Natural fracture clusters are genetically related to stress concentrations (also called stress perturbations) associated with local deformation such a faulting. The mechanical explanation of this phenomenon is that deformation generally initiates at regions where the local stress field is elevated beyond the regional. (2) Regional structural and geologic analysis of the Greater Green River Basin (GGRB). Application of techniques developed and demonstrated during earlier phases of the project for sweet-spot delineation were demonstrated in a relatively new and underexplored play: tight gas from continuous-typeUpper Cretaceous reservoirs of the Greater Green River Basin (GGRB). The effort included data acquisition/processing, base map generation, geophysical and remote sensing analysis and the integration of these data and analyses. (3) Examination of the Table Rock field area in the northern Washakie Basin of the Greater Green River Basin. This effort was performed in support of Union Pacific Resources- and DOE-planned horizontal drilling efforts. The effort comprised acquisition of necessary seismic data and depth-conversion, mapping of major fault geometry, and analysis of displacement vectors, and the development of the natural fracture prediction. (4) Greater Green River Basin Partitioning. Building on fundamental fracture characterization work and prior work performed under this contract, namely structural analysis using satellite and

Past decade and current status of development of naturalgas vehicles (NGVs) in China is described. By the end of 1995, 35 CNG refueling stations and 9 LPG refueling stations had been constructed in 12 regions, and 33,100 vehicles had been converted to run on CNG or LPG. China`s automobile industry, a mainstay of the national economy, is slated for accelerated development over next few years. NGVs will help to solve the problems of environment protection, GHGs mitigation, and shortage of oil supply. The Chinese government has started to promote the development of NGVs. Projects, investment demand, GHG mitigation potential, and development barriers are discussed. China needs to import advanced foreign technologies of CNGs. China`s companies expect to cooperate with foreign partners for import of CNG vehicle refueling compressors, conversions, and light cylinders, etc.

The goal of this research program was to develop and demonstrate a novel gasification technology to produce substitute naturalgas (SNG) from coal. The technology relies on a continuous sequential processing method that differs substantially from the historic methanation or hydro-gasification processing technologies. The thermo-chemistry relies on all the same reactions, but the processing sequences are different. The proposed concept is appropriate for western sub-bituminous coals, which tend to be composed of about half fixed carbon and about half volatile matter (dry ash-free basis). In the most general terms the process requires four steps (1) separating the fixed carbon from the volatile matter (pyrolysis); (2) converting the volatile fraction into syngas (reforming); (3) reacting the syngas with heated carbon to make methane-rich fuel gas (methanation and hydro-gasification); and (4) generating process heat by combusting residual char (combustion). A key feature of this technology is that no oxygen plant is needed for char combustion.

The paper gives the second year's results of an ongoing 4-year program undertaken jointly by the Gas Research Institute and the U.S. EPA to assess the methane (CH4) losses from the U.S. naturalgas industry. he program's objective is to assess the acceptability of naturalgas as ...

Naturalgas is seen by many as the future of American energy: a fuel that can provide energy independence and reduce greenhouse gas emissions in the process. However, there has also been confusion about the climate implications of increased use of naturalgas for electric power and transportation. We propose and illustrate the use of technology warming potentials as a robust and transparent way to compare the cumulative radiative forcing created by alternative technologies fueled by naturalgas and oil or coal by using the best available estimates of greenhouse gas emissions from each fuel cycle (i.e., production, transportation and use). We find that a shift to compressed naturalgas vehicles from gasoline or diesel vehicles leads to greater radiative forcing of the climate for 80 or 280 yr, respectively, before beginning to produce benefits. Compressed naturalgas vehicles could produce climate benefits on all time frames if the well-to-wheels CH(4) leakage were capped at a level 45-70% below current estimates. By contrast, using naturalgas instead of coal for electric power plants can reduce radiative forcing immediately, and reducing CH(4) losses from the production and transportation of naturalgas would produce even greater benefits. There is a need for the naturalgas industry and science community to help obtain better emissions data and for increased efforts to reduce methane leakage in order to minimize the climate footprint of naturalgas. PMID:22493226

Naturalgas is seen by many as the future of American energy: a fuel that can provide energy independence and reduce greenhouse gas emissions in the process. However, there has also been confusion about the climate implications of increased use of naturalgas for electric power and transportation. We propose and illustrate the use of technology warming potentials as a robust and transparent way to compare the cumulative radiative forcing created by alternative technologies fueled by naturalgas and oil or coal by using the best available estimates of greenhouse gas emissions from each fuel cycle (i.e., production, transportation and use). We find that a shift to compressed naturalgas vehicles from gasoline or diesel vehicles leads to greater radiative forcing of the climate for 80 or 280 yr, respectively, before beginning to produce benefits. Compressed naturalgas vehicles could produce climate benefits on all time frames if the well-to-wheels CH4 leakage were capped at a level 45–70% below current estimates. By contrast, using naturalgas instead of coal for electric power plants can reduce radiative forcing immediately, and reducing CH4 losses from the production and transportation of naturalgas would produce even greater benefits. There is a need for the naturalgas industry and science community to help obtain better emissions data and for increased efforts to reduce methane leakage in order to minimize the climate footprint of naturalgas. PMID:22493226

This report summarizes the research conducted during Budget Period One on the project ''Improved NaturalGas Storage Well Remediation''. The project team consisted of Furness-Newburge, Inc., the technology developer; TechSavants, Inc., the technology validator; and Nicor Technologies, Inc., the technology user. The overall objectives for the project were: (1) To develop, fabricate and test prototype laboratory devices using sonication and underwater plasma to remove scale from naturalgas storage well piping and perforations; (2) To modify the laboratory devices into units capable of being used downhole; (3) To test the capability of the downhole units to remove scale in an observation well at a naturalgas storage field; (4) To modify (if necessary) and field harden the units and then test the units in two pressurized injection/withdrawal gas storage wells; and (5) To prepare the project's final report. This report covers activities addressing objectives 1-3. Prototype laboratory units were developed, fabricated, and tested. Laboratory testing of the sonication technology indicated that low-frequency sonication was more effective than high-frequency (ultrasonication) at removing scale and rust from pipe sections and tubing. Use of a finned horn instead of a smooth horn improves energy dispersal and increases the efficiency of removal. The chemical data confirmed that rust and scale were removed from the pipe. The sonication technology showed significant potential and technical maturity to warrant a field test. The underwater plasma technology showed a potential for more effective scale and rust removal than the sonication technology. Chemical data from these tests also confirmed the removal of rust and scale from pipe sections and tubing. Focusing of the underwater plasma's energy field through the design and fabrication of a parabolic shield will increase the technology's efficiency. Power delivered to the underwater plasma unit by a sparkplug repeatedly was

Energy independence and fuel savings are hallmarks of the nation’s energy strategy. The advancement of naturalgas reciprocating engine power generation technology is critical to the nation’s future. A new engine platform that meets the efficiency, emissions, fuel flexibility, cost and reliability/maintainability targets will enable American manufacturers to have highly competitive products that provide substantial environmental and economic benefits in the US and in international markets. Along with Cummins and Waukesha, Caterpillar participated in a multiyear cooperative agreement with the Department of Energy to create a 50% efficiency naturalgas powered reciprocating engine system with a 95% reduction in NOx emissions by the year 2013. This platform developed under this agreement will be a significant contributor to the US energy strategy and will enable gas engine technology to remain a highly competitive choice, meeting customer cost of electricity targets, and regulatory environmental standard. Engine development under the Advanced Reciprocating Engine System (ARES) program was divided into phases, with the ultimate goal being approached in a series of incremental steps. This incremental approach would promote the commercialization of ARES technologies as soon as they emerged from development and would provide a technical and commercial foundation of later-developing technologies. Demonstrations of the Phase I and Phase II technology were completed in 2004 and 2008, respectively. Program tasks in Phase III included component and system development and testing from 2009-2012. Two advanced ignition technology evaluations were investigated under the ARES program: laser ignition and distributed ignition (DIGN). In collaboration with Colorado State University (CSU), a laser ignition system was developed to provide ignition at lean burn and high boost conditions. Much work has been performed in Caterpillar’s DIGN program under the ARES program. This work

Growing supplies of naturalgas have heightened interest in the net impacts of naturalgas on climate. Although its production and consumption result in greenhouse gas emissions, naturalgas most often substitutes for other fossil fuels whose emission rates may be higher. Because naturalgas can be used throughout the sectors of the energy economy, its net impacts on greenhouse gas emissions will depend not only on the leak rates of production and distribution, but also on the use for which naturalgas is substituted. Here, we present our estimates of the net greenhouse gas emissions impacts of substituting naturalgas for other fossil fuels for five purposes: light-duty vehicles, transit buses, residential heating, electricity generation, and export for electricity generation overseas. Emissions are evaluated on a fuel cycle basis, from production and transport of each fuel through end use combustion, based on recent conditions in the United States. We show that displacement of existing coal-fired electricity and heating oil furnaces yield the largest reductions in emissions. The impact of compressed naturalgas replacing petroleum-based vehicles is highly uncertain, with the sign of impact depending on multiple assumptions. Export of liquefied naturalgas for electricity yields a moderate amount of emissions reductions. We further show how uncertainties in upstream emission rates for naturalgas and in the global warming potential of methane influence the net greenhouse gas impacts. Our presentation will make the case that how naturalgas is deployed is crucial to determining how it will impact climate.

A Fossil Energy natural-gas topic has been a part of the DOE Small Business Innovation Research (SBIR) program since 1988. To date, 50 Phase SBIR natural-gas applications have been funded. Of these 50, 24 were successful in obtaining Phase II SBIR funding. The current Phase II natural-gas research projects awarded under the SBIR program and managed by METC are presented by award year. The presented information on these 2-year projects includes project title, awardee, and a project summary. The 1992 Phase II projects are: landfill gas recovery for vehicular naturalgas and food grade carbon dioxide; brine disposal process for coalbed gas production; spontaneous natural as oxidative dimerization across mixed conducting ceramic membranes; low-cost offshore drilling system for naturalgas hydrates; motorless directional drill for oil and gas wells; and development of a multiple fracture creation process for stimulation of horizontally drilled wells.The 1993 Phase II projects include: process for sweetening sour gas by direct thermolysis of hydrogen sulfide; remote leak survey capability for naturalgas transport storage and distribution systems; reinterpretation of existing wellbore log data using neural-based patter recognition processes; and advanced liquid membrane system for naturalgas purification.

Energy use is the primary cause of many environmental problems in the United States and around the world. Fossil fuels, including coal, oil, and naturalgas, supply roughly 90 percent of our energy needs in the United States, and they are directly responsible for urban and industrial air pollution and acid rain. Combustion emissions from fossil fuels also contribute to the Earth's greenhouse effect, and they may play an important role in ozone depletion in the stratosphere, and oxidant depletion in the troposphere. Naturalgas, which is mostly methane, is the least polluting of the fossil fuels. Upon combustion, naturalgas produces lower CO[sub 2], CO, NO[sub x], SO[sub 2], and particulate emissions than either oil or coal. This means that substitution of naturalgas for oil and coal can help mitigate air pollution and the human contribution to the greenhouse effect. However, methane is itself a potent greenhouse gas, and increased production and consumption of naturalgas must be conducted in such a way that gas leakages are minimized. Naturalgas compares well to the other fossil fuels in terms of water quality, preservation of natural ecosystems, and safety. These combined advantages may give naturalgas a more prominent role in the US energy mix. Like other fossil fuels though, naturalgas is nonrenewable and, therefore, not a permanent solution to our energy needs. 40 refs., 15 figs., 1 tab.

The view that naturalgas is thermolytic, coming from decomposing organic debris, has remained almost unchallenged for nearly half a century. Disturbing contradictions exist, however: Oil is found at great depth, at temperatures where only gas should exist and oil and gas deposits show no evidence of the thermolytic debris indicative of oil decomposing to gas. Moreover, laboratory attempts to duplicate the composition of naturalgas, which is typically between 60 and 95+ wt% methane in C{sub 1}-C{sub 4}, have produced insufficient amounts of methane (10 to 60%). It has been suggested that naturalgas may be generated catalytically, promoted by the transition metals in carbonaceous sedimentary rocks. This talk will discuss experimental results that support this hypothesis. Various transition metals, as pure compounds and in source rocks, will be shown to generate a catalytic gas that is identical to naturalgas. Kinetic results suggest robust catalytic activity under moderate catagenetic conditions.

Although Africa has experienced 10 times less hydrocarbon exploration than Western Europe, its proved gas reserves already amount to 220-223 trillion CF or 7% of world reserves, while Europe holds 6% or 167 TCF. Yet Africa marketed only 1.3 TCF in 1982 against Europe's 6.5 TCF. Because of the lack of domestic demand for gas, Africa flares up to 21% of its gas output. Algeria is the continent's primary gas consumer, with Egypt, Libya, and Nigeria trying to expand local gas markets. The vast majority of marketed African gas goes to Europe, either as gas sent through the Trans-Med pipeline or as LNG via tanker.

... Transmission Company, LLC, Transcontinental Gas Pipe Line Company, LLC, and Enterprise Field Services, LLC..., LLC, and Enterprise Field Services, LLC, collectively referred to as the Applicants, in Refugio County... scoping process the Commission will use to gather input from the public and interested agencies on...

The Energy Information Administration's (EIA) Reserves and NaturalGas Division has undertaken an in-depth reevaluation of its programs in an effort to improve the focus and quality of the naturalgas data that it gathers and reports. This article is to inform naturalgas data users of proposed changes and of the opportunity to provide comments and input on the direction that EIA is taking to improve its data.

Naturalgas could be used as a transportation fuel, especially with the recent expansion of U.S. resource and production. This could mean burning naturalgas in an internal combustion engine like most of the vehicles on the road today. Or, with the advanced vehicles now becoming available, other pathways are possible to use naturalgas for personal vehicles. This fact sheet summarizes a comparison of efficiency and environmental metrics for three possible options.

The United States has more oil and gas wells than any other country. As of December 31, 2004, there were more than half a million producing oil wells in the United States. That is more than three times the combined total for the next three leaders: China, Canada, and Russia. The Stripper Well Consortium (SWC) is a partnership that includes domestic oil and gas producers, service and supply companies, trade associations, academia, the Department of Energy’s Strategic Center for NaturalGas and Oil (SCNGO) at the National Energy Technology Laboratory (NETL), and the New York State Energy Research and Development Authority (NYSERDA). The Consortium was established in 2000. This report serves as a final technical report for the SWC activities conducted over the May 1, 2004 to December 1, 2011 timeframe. During this timeframe, the SWC worked with 173 members in 29 states and three international countries, to focus on the development of new technologies to benefit the U.S. stripper well industry. SWC worked with NETL to develop a nationwide request-for-proposal (RFP) process to solicit proposals from the U.S. stripper well industry to develop and/or deploy new technologies that would assist small producers in improving the production performance of their stripper well operations. SWC conducted eight rounds of funding. A total of 132 proposals were received. The proposals were compiled and distributed to an industry-driven SWC executive council and program sponsors for review. Applicants were required to make a formal technical presentation to the SWC membership, executive council, and program sponsors. After reviewing the proposals and listening to the presentations, the executive council made their funding recommendations to program sponsors. A total of 64 projects were selected for funding, of which 59 were fully completed. Penn State then worked with grant awardees to issue a subcontract for their approved work. SWC organized and hosted a total of 14 meetings

For the foreseeable future, most of the demand for naturalgas in the United States will be met with domestic resources. Impediments, or constraints, to developing, producing, and delivering these resources can lead to price increases or supply disruptions. Previous analyses have identified lack of access to naturalgas resources on federal lands as such an impediment. However, various other environmental constraints, including laws, regulations, and implementation procedures, can limit naturalgas development and production on both federal and private lands. This report identifies and describes more than 30 environmental policy and regulatory impediments to domestic naturalgas production. For each constraint, the source and type of impact are presented, and when the data exist, the amount of gas affected is also presented. This information can help decision makers develop and support policies that eliminate or reduce the impacts of such constraints, help set priorities for regulatory reviews, and target research and development efforts to help the nation meet its naturalgas demands.

Naturalgas is becoming increasingly important as a fuel because of its widespread occurrence and because it has a less significant environmental impact than oil. Many of the known gas accumulations were discovered by accident during exploration for oil, but with increasing demand for gas, successful exploration will require a clearer understanding of the factors that control gas distribution and gas composition. Naturalgas is generated by three main processes. In oxygen-deficient, sulfate-free, shallow (few thousand feet) environments bacteria generate biogenic gas that is essentially pure methane with no higher hydrocarbons ({open_quotes}dry gas{close_quotes}). Gas is also formed from organic matter ({open_quotes}kerogen{close_quotes}), either as the initial product from the thermal breakdown of Type III, woody kerogens, or as the final hydrocarbon product from all kerogen types. In addition, gas can be formed by the thermal cracking of crude oil in the deep subsurface. The generation of gas from kerogen requires higher temperatures than the generation of oil. Also, the cracking of oil to gas requires high temperatures, so that there is a general trend from oil to gas with increasing depth. This produces a well-defined {open_quotes}floor for oil{close_quotes}, below which crude oil is not thermally stable. The possibility of a {open_quotes}floor for gas{close_quotes} is less well documented and understanding the limits on naturalgas occurrence was one of the main objectives of this research.

For decades, gas hydrates have been discussed as a potential resource, particularly for countries with limited access to conventional hydrocarbons or a strategic interest in establishing alternative, unconventional gas reserves. Methane has never been produced from gas hydrates at a commercial scale and, barring major changes in the economics of naturalgas supply and demand, commercial production at a large scale is considered unlikely to commence within the next 15 years. Given the overall uncertainty still associated with gas hydrates as a potential resource, they have not been included in the EPPA model in MITEI’s Future of NaturalGas report. Still, gas hydrates remain a potentially large methane resource and must necessarily be included in any consideration of the naturalgas supply beyond two decades from now.

A system is described that is suitable for use in determining the location of leaks of gases having a background concentration. The system is a point-wise backscatter absorption gas measurement system that measures absorption and distance to each point of an image. The absorption measurement provides an indication of the total amount of a gas of interest, and the distance provides an estimate of the background concentration of gas. The distance is measured from the time-of-flight of laser pulse that is generated along with the absorption measurement light. The measurements are formatted into an image of the presence of gas in excess of the background. Alternatively, an image of the scene is superimposed on the image of the gas to aid in locating leaks. By further modeling excess gas as a plume having a known concentration profile, the present system provides an estimate of the maximum concentration of the gas of interest.

A probable increase in the use of naturalgas is predicted to occur over the next decade because heightened concerns by the public over air quality are likely to place severe constraints on increased use of coal and petroleum as primary fuels. Congress and the states appear to be preparing to legislate new clean air standards that will be difficult to achieve under present economic conditions using the current mix of hydrocarbon fuels. Naturalgas is a favorable fuel for several reasons. Because it has a high hydrogen-to-carbon ratio, it produces the least amount of carbon dioxide per calorie of any of the hydrocarbon fuels. Combustion of gas in modern burners does not produce significant CO, NO{sub x}, SO{sub 2}, or any of the complex photochemicals responsible for smog and ozone pollution. Supplies of gas are plentiful, with a total domestic recoverable resource base of over 980 tcf estimated by the Potential Gas Agency. Additional gas, not counted in reserve estimates, is present in abandoned fields, where secondary recovery techniques may produce significant quantities. A promising area for increased naturalgas usage in the next decade is electrical power generation, either by substituting gas for oil and coal as a boiler fuel or by generating electricity directly using chemical fuel cells powered by naturalgas and air. Naturalgas-fueled vehicles are another favored technology, due to very low emission levels and because naturalgas can be run in a standard automotive engine with only minor mechanical modifications. Vehicles must carry compressed naturalgas in high-pressure cylinders, but adsorptive materials are being developed to transport significant quantities at reduced pressure. Current technology can pack a 2,400-psi volume-equivalent of naturalgas onto adsorptive material in the same space at only 500 psi.

Cummins Westport Incorporated (CWI) has designed and developed a liquefied naturalgas (LNG) vehicle fuel system that includes a reciprocating pump with the cold end submerged in LNG contained in a vacuum-jacketed tank. This system was tested and analyzed under the U.S. Department of Energy (DOE) Advanced LNG Onboard Storage System (ALOSS) program. The pumped LNG fuel system developed by CWI and tested under the ALOSS program is a high-pressure system designed for application on Class 8 trucks powered by CWI's ISX G engine, which employs high-pressure direct injection (HPDI) technology. A general ALOSS program objective was to demonstrate the feasibility and advantages of a pumped LNG fuel system relative to on-vehicle fuel systems that require the LNG to be ''conditioned'' to saturation pressures that exceeds the engine fuel pressure requirements. These advantages include the capability to store more fuel mass in given-size vehicle and station tanks, and simpler lower-cost LNG refueling stations that do not require conditioning equipment. Pumped LNG vehicle fuel systems are an alternative to conditioned LNG systems for spark-ignition naturalgas and port-injection dual-fuel engines (which typically require about 100 psi), and they are required for HPDI engines (which require over 3,000 psi). The ALOSS program demonstrated the feasibility of a pumped LNG vehicle fuel system and the advantages of this design relative to systems that require conditioning the LNG to a saturation pressure exceeding the engine fuel pressure requirement. LNG tanks mounted on test carts and the CWI engineering truck were repeatedly filled with LNG saturated at 20 to 30 psig. More fuel mass was stored in the vehicle tanks as well as the station tank, and no conditioning equipment was required at the fueling station. The ALOSS program also demonstrated the general viability and specific performance of the CWI pumped LNG fuel system design. The system tested as part of this program is

A transition from a system of coal electricity generation to near-zero emission electricity generation will be central to any effort to mitigate climate change. Naturalgas is increasingly seen as a 'bridge fuel' for transitions form coal to near-zero emission energy sources. However, various studies use different metrics to estimate the climate impact of naturalgas utilization, and led to differing conclusions. Thus, there is a need to identify the key factors affecting the climate effects of naturalgas and coal electricity production, and to present these climate effects in as clear and transparent a way as possible. Here, we identify power plant efficiency and methane leakage rate as the key factors that explain most of the variance in greenhouse gas emissions by naturalgas and coal power plants. We then develop a power plant GHG emission model, apply available life-cycle parameters to calculate associated CO2 and CH4 emissions and assess climate effects. Simple underlying physical changes can be obscured by abstract evaluation metrics, thus we base our discussion on temperature changes over time. We find that, during the period of plant operation, if there is substantial naturalgas leakage, naturalgas plants can produce greater near-term warming than a coal plant with the same power output. If leakage rates can be made to be low and efficiency high, naturalgas plants can produce some reduction in near-term warming. However, without carbon capture and storage naturalgas power plants cannot achieve the deep reductions that would be required to avoid substantial contribution to additional global warming. Achieving climate benefits from the use of naturalgas depends on building high-efficiency naturalgas plants, controlling methane leakage, and on developing a policy environment that assures a transition to future lower-emission technologies. For more information please see http://iopscience.iop.org/1748-9326/9/11/114022/article .

The objective of the Cummins ARES program, in partnership with the US Department of Energy (DOE), is to develop advanced naturalgas engine technologies that increase engine system efficiency at lower emissions levels while attaining lower cost of ownership. The goals of the project are to demonstrate engine system achieving 50% Brake Thermal Efficiency (BTE) in three phases, 44%, 47% and 50% (starting baseline efficiency at 36% BTE) and 0.1 g/bhp-hr NOx system out emissions (starting baseline NOx emissions at 2 – 4 g/bhp-hr NOx). Primary path towards above goals include high Brake Mean Effective Pressure (BMEP), improved closed cycle efficiency, increased air handling efficiency and optimized engine subsystems. Cummins has successfully demonstrated each of the phases of this program. All targets have been achieved through application of a combined set of advanced base engine technologies and Waste Heat Recovery from Charge Air and Exhaust streams, optimized and validated on the demonstration engine and other large engines. The following architectures were selected for each Phase: Phase 1: Lean Burn Spark Ignited (SI) Key Technologies: High Efficiency Turbocharging, Higher Efficiency Combustion System. In production on the 60/91L engines. Over 500MW of ARES Phase 1 technology has been sold. Phase 2: Lean Burn Technology with Exhaust Waste Heat Recovery (WHR) System Key Technologies: Advanced Ignition System, Combustion Improvement, Integrated Waste Heat Recovery System. Base engine technologies intended for production within 2 to 3 years Phase 3: Lean Burn Technology with Exhaust and Charge Air Waste Heat Recovery System Key Technologies: Lower Friction, New Cylinder Head Designs, Improved Integrated Waste Heat Recovery System. Intended for production within 5 to 6 years Cummins is committed to the launch of next generation of large advanced NG engines based on ARES technology to be commercialized worldwide.

The Powder River Basin in northeastern Wyoming is one of the most active areas of coalbed naturalgas (CBNG) development in the western United States. This resource provides clean energy but raises environmental concerns. Primary among these is the disposal of water that is co-produced with the gas during depressurization of the coal seam. Beginning with a few producing wells in Wyoming's Powder River Basin (PRB) in 1987, CBNG well numbers in this area increased to over 13,600 in 2004, with projected growth to 20,900 producing wells in the PRB by 2010. CBNG development is continuing apace since 2004, and CBNG is now being produced or evaluated in four other Wyoming coal basins in addition to the PRB, with roughly 3500-4000 new CBNG wells permitted statewide each year since 2004. This is clearly a very valuable source of clean fuel for the nation, and for Wyoming the economic benefits are substantial. For instance, in 2003 alone the total value of Wyoming CBNG production was about $1.5 billion, with tax and royalty income of about $90 million to counties, $140 million to the state, and $27 million to the federal government. In Wyoming, cumulative CBNG water production from 1987 through December 2004 was just over 380,000 acre-feet (2.9 billion barrels), while producing almost 1.5 trillion cubic feet (tcf) of CBNG gas statewide. Annual Wyoming CBNG water production in 2003 was 74,457 acre-feet (577 million barrels). Total production of CBNG water across all Wyoming coal fields could total roughly 7 million acre-feet (55.5 billion barrels), if all of the recoverable CBNG in the projected reserves of 31.7 tcf were produced over the coming decades. Pumping water from coals to produce CBNG has been designated a beneficial water use by the Wyoming State Engineer's Office (SEO), though recently the SEO has limited this beneficial use designation by requiring a certain gas/water production ratio. In the eastern part of the PRB where CBNG water is generally of good quality

The Office of NaturalGas and Petroleum Import and Export Activities prepares quarterly reports summarizing the data provided by companies authorized to import or export naturalgas. Companies are required, as a condition of their authorizations, to file quarterly reports. This report is for the second quarter of 1997 (April through June).

As an alternative to imported oil, scientists at the Department of Energy’s Savannah River National Laboratory are looking at abundant, domestically sourced naturalgas, as an alternative transportation fuel. SRNL is investigating light, inexpensive, adsorbed naturalgas storage systems that may fuel the next generation of automobiles.

This unit explores a recent and controversial theory of the origin of much of the Earth's naturalgas and oil. The materials provided will give students the opportunity to: (1) gain an understanding of science and what is involved in the acceptance or rejection of theories; (2) learn about fossil fuels, especially naturalgas; (3) learn the…

The outlook for increased use of naturalgas for fueling autos depends primarily on comparative fuel prices and comparative vehicle prices, according to David E. Gushee, a senior fellow in environmental policy at the Library of Congress in Washington, D.C. Compressed naturalgas may be a more efficient fuel than gasoline, but costs of fuel distribution and engine design can add significantly to its total price. Currently, naturalgas is less expensive than gasoline at the retail level, but this price advantage depends on government and industry subsidies. For naturalgas to stay competitive in the future, these subsidies likely will have to continue, says Gushee. The pump price of naturalgas will have to remain low if naturalgas-powered vehicles are to succeed in the market place, because such vehicles currently cost about $2,500 to $5,000 more than a comparable gasoline-powered car. Gushee says that even with mass production, the projected price difference will be about $800 per car. The challenges facing compressed naturalgas are daunting, especially considering that even in nations where naturalgas receives significant tax advantages, its penetration has not exceeded 15 percent.

This report examines how well the current national naturalgas pipeline network has been able to handle today's market demand for naturalgas. In addition, it identifies those areas of the country where pipeline utilization is continuing to grow rapidly and where new pipeline capacity is needed or is planned over the next several years.

A method for preparing a naturalgas storage vessel for shipment is presented. The gas is stored at 3,000 pounds per square inch. The safety precautions to be observed are emphasized. The equipment and process for purging the tank and sampling the exit gas flow are described. A diagram of the pressure vessel and the equipment is provided.

This research tests a form of the efficient markets hypothesis in the market for naturalgas futures. Unlike other studies of future markets, the test for market efficiency is conducted at numerous locations which comprise the naturalgas spot market in addition to the delivery location specified in the futures contract. Naturalgas spot and futures prices are found to be nonstationary and accordingly are modeled using recently developed maximum likelihood cointegrated with nearly all of the spot market prices across the national network of gas pipelines. The hypothesis of market efficiency can be rejected in 3 of the 13 spot markets. 29 refs., 1 fig., 2 tabs.

Efficient scrubbing of mercury vapour from naturalgas streams has been demonstrated both in the laboratory and on an industrial scale, using chlorocuprate(II) ionic liquids impregnated on high surface area porous solid supports, resulting in the effective removal of mercury vapour from naturalgas streams. This material has been commercialised for use within the petroleum gas production industry, and has currently been running continuously for three years on a naturalgas plant in Malaysia. Here we report on the chemistry underlying this process, and demonstrate the transfer of this technology from gram to ton scale. PMID:25722100

An analysis of the lifecycle greenhouse gas (GHG) emissions associated with naturalgas use recently published by Howarth et al. (2011) stated that use of naturalgas produced from shale formations via hydraulic fracturing would generate greater lifecycle GHG emissions than petro...

The Office of NaturalGas and Petroleum Import and Export Activities prepares quarterly reports showing naturalgas import and export activity. Companies are required to file quarterly reports. Attachments show the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the 5 most recent reporting quarters, volumes and prices of gas purchased by long-term importers and exporters during the past 12 months, volume and price data for gas imported on a short-term or spot market basis, and the gas exported on a short-term or spot market basis to Canada and Mexico.

The Office of NaturalGas and Petroleum Import and Export Activities prepares quarterly reports showing naturalgas import and export activity. Companies are required to file quarterly reports. Attachments show the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the 5 most recent quarters, volumes and prices of gas purchased by long-term importers and exporters during the past 12 months, volume and price data for gas imported on a short-term or spot market basis, and the gas exported on a short-term or spot market basis to Canada and Mexico.

The Office of NaturalGas and Petroleum Import and Export Activities prepares quarterly reports showing naturalgas import and export activity. Companies are required to file quarterly reports. Attachments show the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the five most recent quarters, volumes and prices of gas purchased by long-term importers and exporters during the past 12 months, volume and price data for gas imported on a short-term or spot market basis, and the gas exported on a short-term or spot market basis to Canada and Mexico.

Naturalgas hydrates occur on the ocean floor in such great volumes that they contain twice as much carbon as all known coal, oil and conventional naturalgas deposits. Releases of this gas caused by sediment slides and other natural causes have resulted in huge slugs of gas saturated water with density too low to float a ship, and enough localized atmospheric contamination to choke air aspirated aircraft engines. The unexplained disappearances of ships and aircraft along with their crews and passengers in the Bermuda Triangle may be tied to the natural venting of gas hydrates. The paper describes what gas hydrates are, their formation and release, and their possible link to the mystery of the Bermuda Triangle.

The Energy Modeling Forum (EMF) was established in 1976 at Stanford University to provide a structural framework within which energy experts, analysts, and policymakers could meet to improve their understanding of critical energy problems. The ninth EMF study, North American NaturalGas Markets, was conducted by a working group comprised of leading naturalgas analysts and decision-makers from government, private companies, universities, and research and consulting organizations. The EMF 9 working group met five times from October 1986 through June 1988 to discuss key issues and analyze naturalgas markets. This third volume includes technical papers that support many of the conclusions discussed in the EMF 9 summary report (Volume 1) and full working group report (Volume 2). These papers discuss the results from the individual models as well as some nonmodeling analysis related to US naturalgas imports and industrial naturalgas demand. Individual papers have been processed separately for inclusion in the Energy Science and Technology Database.

The Energy Modeling Forum (EMF) was established in 1976 at Stanford University to provide a structural framework within which energy experts, analysts, and policymakers could meet to improve their understanding of critical energy problems. The ninth EMF study, North American NaturalGas Markets, was conducted by a working group comprised of leading naturalgas analysts and decision-makers from government, private companies, universities, and research and consulting organizations. The EMF 9 working group met five times from October 1986 through June 1988 to discuss key issues and analyze naturalgas markets. This third volume includes technical papers that support many of the conclusions discussed in the EMF 9 summary report (Volume 1) and full working group report (Volume 2). These papers discuss the results from the individual models as well as some nonmodeling analysis related to US naturalgas imports and industrial naturalgas demand. Individual papers have been processed separately for inclusion in the Energy Science and Technology Database.

Recent dramatic changes in naturalgas markets have significant implications for the scope and direction of DOE`s upstream as well as downstream naturalgas R&D. Open access transportation changes the way gas is bought and sold. The end of the gas deliverability surplus requires increased reserve development above recent levels. Increased gas demand for power generation and other new uses changes the overall demand picture in terms of volumes, locations and seasonality. DOE`s NaturalGas Strategic Plan requires that its R&D activities be evaluated for their ability to provide adequate supplies of reasonably priced gas. Potential R&D projects are to be evaluated using a full fuel cycle, benefit-cost approach to estimate likely market impact as well as technical success. To assure R&D projects are evaluated on a comparable basis, METC has undertaken the development of a comprehensive naturalgas technology evaluation framework. Existing energy systems models lack the level of detail required to estimate the impact of specific upstream naturalgas technologies across the known range of geological settings and likely market conditions. Gas Systems Analysis Model (GSAM) research during FY 1993 developed and implemented this comprehensive, consistent naturalgas system evaluation framework. Rather than a isolated research activity, however, GSAM represents the integration of many prior and ongoing naturalgas research efforts. When complete, it will incorporate the most current resource base description, reservoir modeling, technology characterization and other geologic and engineering aspects developed through recent METC and industry gas R&D programs.

The present invention provides a system and method for producing substitute naturalgas and electricity, while mitigating production of any greenhouse gasses. The system includes a hydrogasification reactor, to form a gas stream including naturalgas and a char stream, and an oxygen burner to combust the char material to form carbon oxides. The system also includes an algae farm to convert the carbon oxides to hydrocarbon material and oxygen.

An estimate of total naturalgas resource potential of northern Alaska can be obtained by summing known gas reserves in oil and gas fields (35 TCF), mean estimates of undiscovered nonassociated (61 TCF) and associated (12 TCF) gas resources in NPRA, and mean estimates of undiscovered nonassociated (4 TCF) and associated (5 TCF) gas resources in the 1002 area of ANWR; this yields a total of 117 TCF. When estimates of undiscovered gas resources for non-Federal lands are released in 2005, that total will increase by a non-trivial amount. Thus, the conventional naturalgas resource potential of onshore and State offshore areas totals well over 100 TCF. The inclusion of the MMS mean estimate (96 TCF) for undiscovered gas resources in the Beaufort and Chukchi planning areas of the Federal offshore extends that total above 200 TCF.

Naturalgas is increasingly becoming a major contributor in the industrial development of most Middle Eastern countries. Demand there will rise steeply in coming years. This is because of the abundant and growing naturalgas resources in the region, the economic benefits of using local resources, as well as increased emphasis on a cleaner environment. Today, proved reserves of naturalgas in the Middle East are 45 trillion cu meters (tcm), or 1,488 trillion cu ft (tcf). This is over 30% of the world's naturalgas reserves. A table presents data on reserves and production of naturalgas in the region. About 20% of this gross production is rein-injecting for oil field pressure maintenance, 13% is flared or vented, and 7% is accounted as losses. The remaining 60% represents consumption in power generation, water desalination, petrochemicals and fertilizers production, aluminum and copper smelting, and fuel for refineries and other industries. The use of naturalgas in these various industries is discussed. Thirteen tables present data on gas consumption by country and sector, power generation capacity, major chemicals derived from naturalgas, and petrochemical plant capacities.

Naturalgas has the potential to increase the biofuel production output by combining gas- and biomass-to-liquids (GBTL) processes followed by naphtha and diesel fuel synthesis via Fischer-Tropsch (FT). This study reflects on the use of commercial-ready configurations of GBTL technologies and the environmental impact of enhancing biofuels with naturalgas. The autothermal and steam-methane reforming processes for naturalgas conversion and the gasification of biomass for FT fuel synthesis are modeled to estimate system well-to-wheel emissions and compare them to limits established by U.S. renewable fuel mandates. We show that naturalgas can enhance FT biofuel production by reducing the need for water-gas shift (WGS) of biomass-derived syngas to achieve appropriate H2/CO ratios. Specifically, fuel yields are increased from less than 60 gallons per ton to over 100 gallons per ton with increasing naturalgas input. However, GBTL facilities would need to limit naturalgas use to less than 19.1% on a LHV energy basis (7.83 wt %) to avoid exceeding the emissions limits established by the Renewable Fuels Standard (RFS2) for clean, advanced biofuels. This effectively constitutes a blending limit that constrains the use of naturalgas for enhancing the biomass-to-liquids (BTL) process. PMID:26010031

LDEF (Prelaunch), AO175 : Evaluation of Long-Duration Exposure to the Natural Space Environment on Graphite-Polyimide and Graphite-Epoxy Mechanical Properties, Tray A01 The Graphite-Polyimide and Graphite-Epoxy Mechanical Properties experiment is located in two (2) three (3) inch deep peripheral trays, A01 and A07. The experiment hardware configuration in the A01 tray consists of a graph- ite-epoxy honeycomb sandwich panel in the lower one half (1/2) of the tray, a graphite-epoxy panel in the upper right one third (1/3rd) section and two (2) graphite-polyimide panels, one in the upper center and one in the upper left sections of the experiment tray. The panels are supported by a substructure and held in place with aluminum strips and non-magnetic stainless steel fasteners. The mounting system, designed to allow for differential thermal expansion, minimizes the risk of inducing high stresses into the test panels.

Naturalgas provides more than one-fifth of all the primary energy used in the United States. Much raw gas is `subquality`, that is, it exceeds the pipeline specifications for nitrogen, carbon dioxide, and/or hydrogen sulfide content, and much of this low-quality naturalgas cannot be produced economically with present processing technology. Against this background, a number of industry-wide trends are affecting the naturalgas industry. Despite the current low price of naturalgas, long-term demand is expected to outstrip supply, requiring new gas fields to be developed. Several important consequences will result. First, gas fields not being used because of low-quality products will have to be tapped. In the future, the proportion of the gas supply that must be treated to remove impurities prior to delivery to the pipeline will increase substantially. The extent of treatment required to bring the gas up to specification will also increase. Gas Research Institute studies have shown that a substantial capital investment in facilities is likely to occur over the next decade. The estimated overall investment for all gas processing facilities up to the year 2000 alone is approximates $1.2 Billion, of which acid gas removal and sulfur recovery are a significant part in terms of invested capital. This large market size and the known shortcomings of conventional processing techniques will encourage development and commercialization of newer technologies such as membrane processes. Second, much of today`s gas production is from large, readily accessible fields. As new reserves are exploited, more gas will be produced from smaller fields in remote or offshore locations. The result is an increasing need for technology able to treat small-scale gas streams.

For the last fifteen years, the naturalgas price forecasting experts have had a terrible record of forecasting future naturalgas prices. (In the early 80`s, the gas price was forecasted to be over $10/MMBtu in the late 80`s). To make matters even worse, they can`t seem to understand why the price is what it is, even in hindsight. If these experts can`t even get it right in hindsight, how can one ever expect to get it right in foresight? It is concluded that the traditional laws of supply and demand don`t work very well in this new quasi-regulated naturalgas industry. Evidently, Social Influences and Political Influences are more important than the Economic Influence on naturalgas prices.

The question of when gas hydrate will become a commercially viable resource most concerns those nations with the most severe energy deficiencies. With the vast potential attributed to gas hydrate as a new gas play, the interest is understandable. Yet the resource potential of gas hydrate has persistently remained just over the horizon. While technical and economic hurdles have pushed back the timeline for development, considerable progress has been made in the past five years. An important lesson learned is that an analysis of the factors that control the formation of high grade hydrate deposits must be carried out so that both exploration and recovery scenarios can be modeled and engineered. Commercial hydrate development requires high concentrations of hydrate in porous, permeable reservoirs. It is only from such deposits that gas may be recovered in commercial quantities. While it is unrealistic to consider the global potential of gas hydrate to be in the hundreds of thousands of tcfs, there is a strong potential in the hundreds of tcfs or thousands of tcfs. Press releases from several national gas hydrate research programs have reported gas hydrate "discoveries". These are, in fact, hydrate shows that provide proof of the presence of hydrate where it may previously only have been predicted. Except in a few isolated areas, valid resource assessments remain to be accomplished through the identification of suitable hosts for hydrate concentrations such as sandstone reservoirs. A focused exploration effort based on geological and depositional characteristics is needed that addresses hydrate as part of a larger petroleum system. Simply drilling in areas that have identifiable bottom simulating reflectors (BSRs) is unlikely to be a viable exploration tool. It is very likely that with drilling on properly identified targets, commercial development could become a reality in less than a decade.

There are applications where the combined combustion of coal and naturalgas offers potential advantages over the use of either coal or naturalgas alone. For example, low volatile coals or low volatile chars derived from treatment or gasification processes can be of limited use during to their poor flammability characteristics. However, the use of naturalgas in conjunction with the solid fuel can provide the necessary volatiles'' to enhance the combustion. In addition, naturalgas provides a clean fuel source of fuel which, in cofiring situations, can extend the usefulness of coals with high sulfur content. The addition of naturalgas may reduce SO{sub x} emission through increased sulfur retention in the ash and reduce NO{sub x} emissions by varying local stoichiometry and temperature levels. In this research program, studies of combined coal and naturalgas combustion will provide particle ignition, burnout rates and ash characterization, that will help clarify the effect of coal and naturalgas and identify the controlling parameters and mechanisms.

This paper examines the extent to which limitations in the transportation system for the naturalgas market in the United States narrows the effectiveness of the NYMEX naturalgas future contract as a hedging instrument and why a second contract with a different delivery point was approved during 1995. We find that the NYMEX contract is an effective hedging instrument for gas sold into pipelines for consumption in southern, eastern and Midwestern states, but does not provide an effective hedge for gas sold for Rocky Mountain and West Coast states. 10 refs., 3 tabs.

Naturalgas is becoming rapidly the optimal choice for fueling new generating units in electric power system driven by abundant naturalgas supplies and environmental regulations that are expected to cause coal-fired generation retirements. The growing reliance on naturalgas as a dominant fuel for electricity generation throughout North America has brought the interaction between the naturalgas and power grids into sharp focus. The primary concern and motivation of this research is to address the emerging interdependency issues faced by the electric power and naturalgas industry. This thesis provides a comprehensive analysis of the interactions between the two systems regarding the short-term operation and long-term infrastructure planning. Naturalgas and renewable energy appear complementary in many respects regarding fuel price and availability, environmental impact, resource distribution and dispatchability. In addition, demand response has also held the promise of making a significant contribution to enhance system operations by providing incentives to customers for a more flat load profile. We investigated the coordination between naturalgas-fired generation and prevailing nontraditional resources including renewable energy, demand response so as to provide economical options for optimizing the short-term scheduling with the intense naturalgas delivery constraints. As the amount and dispatch of gas-fired generation increases, the long-term interdependency issue is whether there is adequate pipeline capacity to provide sufficient gas to naturalgas-fired generation during the entire planning horizon while it is widely used outside the power sector. This thesis developed a co-optimization planning model by incorporating the naturalgas transportation system into the multi-year resource and transmission system planning problem. This consideration would provide a more comprehensive decision for the investment and accurate assessment for system adequacy and

This paper first describes the state-of-the-art of compressed naturalgas (CNG) technologies and evaluates the market prospects for CNG vehicles in Beijing. An analysis of the naturalgas resource supply for fleet vehicles follows. The costs and benefits of establishing naturalgas filling stations and promoting the development of vehicle technology are evaluated. The quantity of GHG reduction is calculated. The objective of the paper is to provide information of transfer niche of CNG vehicle and equipment production in Beijing. This paper argues that the development of CNG vehicles is a cost-effective strategy for mitigating both air pollution and GHG.

Thermoacoustic heat engines and refrigerators are being developed for liquefaction of naturalgas. This is the only technology capable of producing refrigeration power at cryogenic temperatures with no moving parts. A prototype, with a projected naturalgas liquefaction capacity of 500 gallons/day, has been built and tested. The power source is a naturalgas burner. Systems are developed with liquefaction capacities up to 10,000 to 20,000 gallons per day. The technology, the development project, accomplishments and applications are discussed.

Efforts this quarter have concentrated on design and planning for of a 50 MM scf/d dehydration skid testing at ChevronTexaco's Headlee Gas Plant in Odessa, TX. Potting and module materials testing concluded. Construction of the bench-scale equipment continued and a pre-engineering study on a subsea application of the technology was performed cofunded contracts with Research Partnership for Secure Energy for America and Gas Research Institute. GTI has decreased the effort under this contract pending DOE's obligation of the total contract funding.

Gas hydrates are crystalline substances composed of water and gas, mainly methane, in which a solid-water lattice accommodates gas molecules in a cage-like structure, or clathrate. These substances often have been regarded as a potential (unconventional) source of naturalgas. Significant quantities of naturally occurring gas hydrates have been detected in many regions of the Arctic including Siberia, the Mackenzie River Delta, and the North Slope of Alaska. On the North Slope, the methane-hydrate stability zone is areally extensive beneath most of the coastal plain province and has thicknesses as great as 1000 meters in the Prudhoe Bay area. Gas hydrates have been identified in 50 exploratory and production wells using well-log responses calibrated to the response of an interval in one well where gas hydrates were recovered in a core by ARCO Alaska and EXXON. Most of these gas hydrates occur in six laterally continuous Upper Cretaceous and lower Tertiary sandstone and conglomerate units; all these gas hydrates are geographically restricted to the area overlying the eastern part of the Kuparuk River Oil Field and the western part of the Prudhoe Bay Oil Field. The volume of gas within these gas hydrates is estimated to be about 1.0 {times} 10{sup 12} to 1.2 {times} 10{sup 12} cubic meters (37 to 44 trillion cubic feet), or about twice the volume of conventional gas in the Prudhoe Bay Field. Geochemical analyses of well samples suggest that the identified hydrates probably contain a mixture of deep-source thermogenic gas and shallow microbial gas that was either directly converted to gas hydrate or first concentrated in existing traps and later converted to gas hydrate. The thermogenic gas probably migrated from deeper reservoirs along the same faults thought to be migration pathways for the large volumes of shallow, heavy oil that occur in this area. 51 refs., 11 figs., 3 tabs.

This final report uses ROSAT observations to analyze two different studies. These studies are: Analysis of Mass Profiles and Cooling Flows of Bright, Early-Type Galaxies; and Surface Brightness Profiles and Energetics of Intracluster Gas in Cool Galaxy Clusters.

This measure guideline covers installation of high-efficiency gas furnaces, including: when to install a high-efficiency gas furnace as a retrofit measure; how to identify and address risks; and the steps to be used in the selection and installation process. The guideline is written for Building America practitioners and HVAC contractors and installers. It includes a compilation of information provided by manufacturers, researchers, and the Department of Energy as well as recent research results from the Partnership for Advanced Residential Retrofit (PARR) Building America team.

This Measure Guideline covers installation of high-efficiency gas furnaces. Topics covered include when to install a high-efficiency gas furnace as a retrofit measure, how to identify and address risks, and the steps to be used in the selection and installation process. The guideline is written for Building America practitioners and HVAC contractors and installers. It includes a compilation of information provided by manufacturers, researchers, and the Department of Energy as well as recent research results from the Partnership for Advanced Residential Retrofit (PARR) Building America team.

Shale gas production represents a large potential source of naturalgas for the nation. The scale and rapid growth in shale gas development underscore the need to better understand its environmental implications, including water consumption. This study estimates the water consumed over the life cycle of conventional and shale gas production, accounting for the different stages of production and for flowback water reuse (in the case of shale gas). This study finds that shale gas consumes more water over its life cycle (13-37 L/GJ) than conventional naturalgas consumes (9.3-9.6 L/GJ). However, when used as a transportation fuel, shale gas consumes significantly less water than other transportation fuels. When used for electricity generation, the combustion of shale gas adds incrementally to the overall water consumption compared to conventional naturalgas. The impact of fuel production, however, is small relative to that of power plant operations. The type of power plant where the naturalgas is utilized is far more important than the source of the naturalgas. PMID:24004382

This study provides a preliminary assessment of the potential for determining probabilities of future natural-gas-supply interruptions by combining long-range weather forecasts and natural-gas supply/demand projections. An illustrative example which measures the probability of occurrence of heating-season natural-gas curtailments for industrial users in the southeastern US is analyzed. Based on the information on existing long-range weather forecasting techniques and naturalgas supply/demand projections enumerated above, especially the high uncertainties involved in weather forecasting and the unavailability of adequate, reliable natural-gas projections that take account of seasonal weather variations and uncertainties in the nation's energy-economic system, it must be concluded that there is little possibility, at the present time, of combining the two to yield useful, believable probabilities of heating-season gas curtailments in a form useful for corporate and government decision makers and planners. Possible remedial actions are suggested that might render such data more useful for the desired purpose in the future. The task may simply require the adequate incorporation of uncertainty and seasonal weather trends into modeling systems and the courage to report projected data, so that realistic naturalgas supply/demand scenarios and the probabilities of their occurrence will be available to decision makers during a time when such information is greatly needed.

The current expansion of naturalgas (NG) development in the United States requires an understanding of how this change will affect the naturalgas industry, downstream consumers, and economic growth in order to promote effective planning and policy development. The impact of this expansion may propagate through the NG system and US economy via changes in manufacturing, electric power generation, transportation, commerce, and increased exports of liquefied naturalgas. We conceptualize this problem as supply shock propagation that pushes the NG system and the economy away from its current state of infrastructure development and level of naturalgas use. To illustrate this, the project developed two core modeling approaches. The first is an Agent-Based Modeling (ABM) approach which addresses shock propagation throughout the existing naturalgas distribution system. The second approach uses a System Dynamics-based model to illustrate the feedback mechanisms related to finding new supplies of naturalgas - notably shale gas - and how those mechanisms affect exploration investments in the naturalgas market with respect to proven reserves. The ABM illustrates several stylized scenarios of large liquefied naturalgas (LNG) exports from the U.S. The ABM preliminary results demonstrate that such scenario is likely to have substantial effects on NG prices and on pipeline capacity utilization. Our preliminary results indicate that the price of naturalgas in the U.S. may rise by about 50% when the LNG exports represent 15% of the system-wide demand. The main findings of the System Dynamics model indicate that proven reserves for coalbed methane, conventional gas and now shale gas can be adequately modeled based on a combination of geologic, economic and technology-based variables. A base case scenario matches historical proven reserves data for these three types of naturalgas. An environmental scenario, based on implementing a $50/tonne CO 2 tax results in less proven

Efforts this quarter have concentrated on design of and planning for a 50 MM scf/d dehydration skid testing at ChevronTexaco's Headlee Gas Plant in Odessa, TX. Potting and module materials testing concluded. Construction of the bench-scale equipment continued. GTI has decreased the effort under this contract pending DOE's obligation of the total contract funding.

The Office of Fuels Programs prepares quarterly reports summarizing the data provided by companies authorized to import or export naturalgas. Companies are required, as a condition of their authorizations, to file quarterly reports with the OFP. This quarter`s focus is market penetration of gas imports into New England. Attachments show the following: % takes to maximum firm contract levels and weighted average per unit price for the long-term importers, volumes and prices of gas purchased by long-term importers and exporters, volumes and prices for gas imported on short-term or spot market basis, and gas exported short-term to Canada and Mexico.

An odor in natural and LP gases is necessary. The statistics are overwhelming; when gas customers can smell a leak before the percentage of gas in air reaches a combustible mixture, the chances of an accident are greatly reduced. How do gas companies determine if there is sufficient odor reaching every gas customers home? Injection equipment is important. The rate and quality of odorant is important. Nevertheless, precision odorization alone does not guarantee that customers` homes always have gas with a readily detectable odor. To secure that goal, odor monitoring instruments are necessary.

The work plan for the quarter of October 1, 1997--December 31, 1997 consisted of two tasks: (1) Present results of Rulison field test at various conferences, seminars, and to Barrett Resources and Snyder Oil Co. and (2) Continue work into developing a predictive quantitative method for locating fault-related natural fractures. The first task was completed during this reporting period. The second task continues the beginning of quantitative fracture mechanics analysis of the geologic processes that are involved for the development of fault-related natural fractures. The goal of this work is to develop a predictive capability of locating natural fractures prior to drilling.

This invention relates to a new process for the direct conversion of naturalgas or methane into gasoline-range hydrocarbons (i.e., synthetic transportation fuels or lower olefins) via catalytic condensation using superacid catalysts.

This report documents the objectives, analytical approach and development of the World Energy Projection System Plus (WEPS ) NaturalGas Model. It also catalogues and describes critical assumptions, computational methodology, parameter estimation techniques, and model source code.

This report presents an analysis of residential naturalgas consumption trends in the United States through 2009 and analyzes consumption trends for the United States as a whole (1990 through 2009) and for each Census division (1998 through 2009).

Checklists have been compiled for planning, design, construction, startup and debugging, and operation of liquefied naturalgas facilities. Lists include references to pertinent safety regulations. Methods described are applicable to handling of other hazardous materials.

This report documents the objectives, analytical approach and development of the International NaturalGas Model (INGM). It also catalogues and describes critical assumptions, computational methodology, parameter estimation techniques, and model source code.

Provides information, tips, references, and materials to high school and college level geography teachers on developing a unit on naturalgas. Data are presented in the form of tables, maps, figures, and textual analysis. (Author/DB)

Nitrogen-absorbing and -desorbing compositions, novel ligands and transition metal complexes, and methods of using the same, which are useful for the selective separation of nitrogen from other gases, especially naturalgas.

A bioremediation system for the removal of chlorinated solvents from ground water and sediments is described. The system involves the the in-situ injection of naturalgas (as a microbial nutrient) through an innovative configuration of horizontal wells.

Efforts this quarter have concentrated on design and planning for of a 50 MM scf/d dehydration skid testing at ChevronTexaco's Headlee Gas Plant in Odessa, TX. Potting and module materials testing continued. Construction of the bench-scale equipment continued. Additional funding to support the test was obtained through a contract with Research Partnership for Secure Energy for America. GTI has decreased the effort under this contract pending DOE's obligation of the total contract funding.

Naturalgas has emerged as one of the primary options for satisfying the need for environmentally clean energy: the resource base is large, it is the cleanest burning of the fossil fuels, and it can be used efficiently. New engine, combustion, and energy conversion technologies are emerging that will result in use of naturalgas in electric generation, emissions reduction, transportation, and residential and commercial cooling. PMID:17738301

This report responds to an August 2011 request from the Department of Energy's Office of Fossil Energy (DOE\\/FE) for an analysis of "the impact of increased domestic naturalgas demand, as exports." Appendix A provides a copy of the DOE\\/FE request letter. Specifically, DOE\\/FE asked the U.S. Energy Information Administration (EIA) to assess how specified scenarios of increased naturalgas exports could affect domestic energy markets, focusing on consumption, production, and prices.

This research investigates the possibility that WTI crude oil and Henry Hub naturalgas prices share a stable link. Economic theory suggests that the two commodities are linked by both supply and demand given that the commodities can be coproduced and many consumers have the ability to switch between the fuels. In general, it would appear that the two commodities support this theory with naturalgas prices tracking crude oil prices fairly well until late 2008. However, since the end of 2008 the two price series have diverged and appear to move independently of each other. Reduced fuel switching capabilities in U.S. industry and electric power generation coupled with increased technology and production from shale formations have potentially changed the driving force behind naturalgas prices. However, a severe recession has impacted world economies over the same time period making the cause of the disparity between crude oil and naturalgas prices unclear. Therefore, this research analyzed the possible long-term link between the two commodities over two timeframes. Using an error correction model that includes exogenous factors affecting the short-run dynamics of naturalgas prices over the period January 1999 through September 2008, I find evidence of a long-run cointegrating relationship between naturalgas and crude oil prices. Additionally, crude oil prices are found to be weakly exogenous to the system, suggesting causality runs from crude oil to naturalgas prices. Extending this series through February 2012 yields much weaker evidence of a cointegrating relationship and provides evidence for the decoupling crude oil and naturalgas prices.

This document is designed to help fleets understand the cost factors associated with fueling infrastructure for compressed naturalgas (CNG) vehicles. It provides estimated cost ranges for various sizes and types of CNG fueling stations and an overview of factors that contribute to the total cost of an installed station. The information presented is based on input from professionals in the naturalgas industry who design, sell equipment for, and/or own and operate CNG stations.

Once the November elections are over, politicians will look again at a windfall profits tax on deregulated naturalgas as a revenue source to balance the 10% personal tax cut scheduled for 1983. This would make New England's economy more competitive because the region consumes relatively little gas and already pays a high price for what it does consume. Of the pending decisions that will affect federal revenues, gas decontrol will have the greatest benefit for New England. (DCK)

System designs of molten carbonate fuel cell power plants are described for central stations using coal and on-site generators operating on naturalgas. Fuel-to-busbar efficiencies are near 50% in coal based systems with turbine bottoming and in simple gas based systems. Coal based systems with more advanced but not fully developed components, and more complex gas based systems approach 60% efficiency.

System designs of molten carbonate fuel cell power plants are described for central stations using coal and on-site generators operating on naturalgas. Fuel-to-busbar efficiencies are near 50% in coal based systems with turbine bottoming and in simple gas based systems. Coal based systems with more advanced but not fully developed components, and more complex gas based systems approach 60% efficiency.

A process for treating naturalgas or other methane-rich gas to remove excess nitrogen. The invention relies on two-stage membrane separation, using methane-selective membranes for the first stage and nitrogen-selective membranes for the second stage. The process enables the nitrogen content of the gas to be substantially reduced, without requiring the membranes to be operated at very low temperatures.

This report summarizes the data provided by companies authorized to import or export naturalgas. Data includes volume and price for long term and short term, and gas exported to Canada and Mexico on a short term or spot market basis.

Allowing people to refuel naturalgas vehicles at home could revolutionize the way we power our cars and trucks. Currently, our nation faces two challenges in enabling naturalgas for transportation. The first is improving the way gas tanks are built for naturalgas vehicles; they need to be conformable, allowing them to fit tightly into the vehicle. The second challenge is improving the way those tanks are refueled while maintaining cost-effectiveness, safety, and reliability. This video highlights two ARPA-E project teams with innovative solutions to these challenges. REL is addressing the first challenge by developing a low-cost, conformable naturalgas tank with an interconnected core structure. Oregon State University and OnBoard Dynamics are addressing the second challenge by developing a self-refueling naturalgas vehicle that integrates a compressor into its engine-using one of the engine's cylinders to compress gas eliminates the need for an expensive at-home refueling system. These two distinct technologies from ARPA-E's MOVE program illustrate how the Agency takes a multi-pronged approach to problem solving and innovation.

Allowing people to refuel naturalgas vehicles at home could revolutionize the way we power our cars and trucks. Currently, our nation faces two challenges in enabling naturalgas for transportation. The first is improving the way gas tanks are built for naturalgas vehicles; they need to be conformable, allowing them to fit tightly into the vehicle. The second challenge is improving the way those tanks are refueled while maintaining cost-effectiveness, safety, and reliability. This video highlights two ARPA-E project teams with innovative solutions to these challenges. REL is addressing the first challenge by developing a low-cost, conformable naturalgas tank with an interconnected core structure. Oregon State University and OnBoard Dynamics are addressing the second challenge by developing a self-refueling naturalgas vehicle that integrates a compressor into its engine-using one of the engine's cylinders to compress gas eliminates the need for an expensive at-home refueling system. These two distinct technologies from ARPA-E's MOVE program illustrate how the Agency takes a multi-pronged approach to problem solving and innovation.

Heightened naturalgas prices have emerged as a key energy-policy challenge for at least the early part of the 21st century. With the recent run-up in gas prices and the expected continuation of volatile and high prices in the near future, a growing number of voices are calling for increased diversification of energy supplies. Proponents of renewable energy and energy efficiency identify these clean energy sources as an important part of the solution. Increased deployment of renewable energy (RE) and energy efficiency (EE) can hedge naturalgas price risk in more than one way, but this paper touches on just one potential benefit: displacement of gas-fired electricity generation, which reduces naturalgas demand and thus puts downward pressure on gas prices. Many recent modeling studies of increased RE and EE deployment have demonstrated that this ''secondary'' effect of lowering naturalgas prices could be significant; as a result, this effect is increasingly cited as justification for policies promoting RE and EE. This paper summarizes recent studies that have evaluated the gas-price-reduction effect of RE and EE deployment, analyzes the results of these studies in light of economic theory and other research, reviews the reasonableness of the effect as portrayed in modeling studies, and develops a simple tool that can be used to evaluate the impact of RE and EE on gas prices without relying on a complex national energy model. Key findings are summarized.

During this quarter, work began on the regional structural and geologic analysis of the greater Green River basin (GGRB) in southwestern Wyoming, northwestern Colorado and northeastern Utah. The ultimate objective of the regional analysis is to apply the techniques developed and demonstrated during earlier phases of the project to sweet-spot delineation in a relatively new and underexplored play: tight gas from continuous-type Upper Cretaceous reservoirs of the GGRB. The primary goal of this work is to partition and high-grade the greater Green River basin for exploration efforts in the Cretaceous tight gas play. The work plan for the quarter of January 1, 1998--March 31, 1998 consisted of three tasks: (1) Acquire necessary data and develop base map of study area; (2) Process data for analysis; and (3) Initiate structural study. The first task and second tasks were completed during this reporting period. The third task was initiated and work continues.

Exploration strategies are needed to identify subtle basement features critical to locating fractured regions in advance of drilling in tight gas reservoirs. The Piceance Basin served as a demonstration site for an analysis utilizing aeromagnetic surveys, remote sensing, Landsat Thematic Mapper, and Side Looking Airborne Radar imagery for the basin and surrounding areas. Spatially detailed aeromagnetic maps were used to to interpret zones of basement structure.

In order to reduce the atmospheric pollution generated by ships, the International Marine Organization has established Emission Controlled Areas. In these areas, nitrogen oxides, sulphur oxides and particulates emission is strongly controlled. From the beginning of 2015, the ECA covers waters 200 nautical miles from the coast of the US and Canada, the US Caribbean Sea area, the Baltic Sea, the North Sea and the English Channel. From the beginning of 2020, strong emission restrictions will also be in force outside the ECA. This requires newly constructed ships to be either equipped with exhaust gas cleaning devices or propelled with emission free fuels. In comparison to low sulphur Marine Diesel and Marine Gas Oil, LNG is a competitive fuel, both from a technical and economical point of view. LNG can be stored in vacuum insulated tanks fulfilling the difficult requirements of marine regulations. LNG must be vaporized and pressurized to the pressure which is compatible with the engine requirements (usually a few bar). The boil-off must be controlled to avoid the occasional gas release to the atmosphere. This paper presents an LNG system designed and commissioned for a Baltic Sea ferry. The specific technical features and exploitation parameters of the system will be presented. The impact of strict marine regulations on the system's thermo-mechanical construction and its performance will be discussed. The review of possible flow-schemes of LNG marine systems will be presented with respect to the system's cost, maintenance, and reliability.

In a naturalgas liquefaction system having a refrigerant storage circuit, a refrigerant circulation circuit in fluid communication with the refrigerant storage circuit, and a naturalgas liquefaction circuit in thermal communication with the refrigerant circulation circuit, a method for liquefaction of naturalgas in which pressure in the refrigerant circulation circuit is adjusted to below about 175 psig by exchange of refrigerant with the refrigerant storage circuit. A variable speed motor is started whereby operation of a compressor is initiated. The compressor is operated at full discharge capacity. Operation of an expansion valve is initiated whereby suction pressure at the suction pressure port of the compressor is maintained below about 30 psig and discharge pressure at the discharge pressure port of the compressor is maintained below about 350 psig. Refrigerant vapor is introduced from the refrigerant holding tank into the refrigerant circulation circuit until the suction pressure is reduced to below about 15 psig, after which flow of the refrigerant vapor from the refrigerant holding tank is terminated. Naturalgas is then introduced into a naturalgas liquefier, resulting in liquefaction of the naturalgas.

Power capacity additions in Asia will at least triple by 2010, and Arthur D. Little Inc. predicts naturalgas can pick up a good 15 percent of that market. The study predicts Asia potentially will need 720 gigawatts of new power generation by 2010, of which 15 percent may be gas-based. This represents a market three times the size of the US market in the same period, and would require more than $1 trillion in investment to finance the power generation projects alone. Six forces are driving new market opportunities for naturalgas in Asia, and have set the stage for major investments in Asian gas-based power generation. They are: New technologies; growing environmental pressures; privatization; alternative energy pricing; gas availability; and continued economic growth. Japan, South Korea and Taiwan already have large, well-established markets for both gas and power that provide minimal opportunities for foreign investment. But the rest of Asia - specifically, India, Pakistan, the Philippines, Vietnam, Indonesia, Malaysia, the People's Republic of China, Thailand, Bangladesh and Myanmar - is still relatively undeveloped, the study said, and gas is emerging as an energy import substitute or export earner. The study found those countries will turn increased environmental awareness and concern into legislation as their economic prosperity grows, leading to a higher future value for naturalgas relative to other fuels. Stricter emissions standards will favor gas over diesel, fuel oil and coal.

Tee idea that naturalgas is the thermal product of organic decomposition has persisted for over half a century. Crude oil is thought to be an important source of gas, cracking to wet gas above 150 C, and dry gas above 200 C. But there is little evidence to support this view. For example, crude oil is proving to be more stable than previously thought and projected to remain intact over geologic time at typical reservoir temperature. Moreover, when oil does crack, the products do not resemble naturalgas. Oil to gas could be catalytic, however, promoted by the transition metals in carbonaceous sediments. This would explain the low temperatures at which naturalgas forms, and the high amounts of methane. This idea gained support recently when the natural progression of oil to dry gas was duplicated in the laboratory catalytically. The authors report here the isotopic composition of catalytic gas generated from crude oil and pure hydrocarbons between 150 and 200 C. {delta}{sup 13}C for C{sub 1} through C{sub 5} was linear with 1/n (n = carbon number) in accordance with theory and typically seen in natural gases. Over extended reaction, isobutane and isopentane remained lighter than their respective normal isomers and the isotopic differentials were constant as all isomers became heavier over time. Catalytic methane, initially {minus}51.87{per_thousand} (oil = {minus}22.5{per_thousand}), progressed to a final composition of {minus}26.94{per_thousand}, similar to the maturity trend seen in natural gases: {minus}50{per_thousand} to {minus}20{per_thousand}. Catalytic gas is thus identical to naturalgas in molecular and isotopic composition adding further support to the view that catalysis by transition metals may be a significant source of naturalgas.

Efforts this quarter have concentrated on field site selection. ChevronTexaco has signed a contract with Kvaerner process Systems for the 50 MM scf/d dehydration skid at their Headlee Gas Plant in Odessa, TX for a commercial-scale test. This will allow the test to go forth. A new test schedule was established with testing beyond the existing contract completion date. Potting and module materials testing continued. Construction of the bench-scale equipment was started. Additional funding to support the test was obtained through a contract with Research Partnership for Secure Energy for America.

Efforts this quarter have concentrated on field site selection. ChevronTexaco has signed a contract with Kvaerner process Systems for the 50 MM scf/d dehydration skid at their Headlee Gas Plant in Odessa, TX for a commercial-scale test. This will allow the test to go forth. A new test schedule was established with testing beyond the existing contract completion date. Potting and module materials testing continued. Construction of the bench-scale equipment was started. Additional funding to support the test was obtained through a contract with Research Partnership for Secure Energy for America.

Evaluation was made of the distribution of radon gas and radiation exposure rates in the four main naturalgas treatment facilities in Syria. The results showed that radiation exposure rates at contact of all equipment were within the natural levels (0.09-0.1 microSvh(-1)) except for the reflex pumps where a dose rate value of 3 microSvh(-1) was recorded. Radon concentrations in Syrian naturalgas varied between 15.4 Bq m(-3) and 1141 Bq m(-3); naturalgas associated with oil production was found to contain higher concentrations than the non-associated naturalgas. In addition, radon concentrations were higher in the central processing facilities than the wellheads; these high levels are due to pressurizing and concentrating processes that enhance radon gas and its decay products. Moreover, the lowest 222Rn concentration was in the naturalgas fraction used for producing sulfur; a value of 80 Bq m(-3) was observed. On the other hand, maximum radon gas and its decay product concentrations in workplace air environments were found to be relatively high in the gas analysis laboratories; a value of 458 Bq m(-3) was observed. However, all reported levels in the workplaces in the four main stations were below the action level set by IAEA for chronic exposure situations involving radon, which is 1000 Bq m(-3). PMID:17905489

Over the past decade, the naturalgas industry landscape in North America has undergone tremendous change. The focus of exploration and production has shifted from ``conventional'' to ``unconventional'' resources, and in particular to shale formations. The fact that some shale formations contain significant volumes of gas-in-place has been known for as long as gas production has taken place - these rocks have always been viewed as the source rock for conventional gas resources. What changed over the past decade is that it became possible to recover this gas directly from the source rock at economically attractive production rates. Horizontal drilling and hydraulic fracturing technologies were key to these developments. This presentation will describe how the unlocking of shale gas through horizontal drilling and fracturing has changed perspectives regarding the scale of the overall recoverable naturalgas resource in the United States. The potential impact of shale gas on the global gas resource will also be described. The results of volumetric assessments of recoverable shale gas will be presented and the critical issue of uncertainty surrounding these estimates will be highlighted. The economics of shale gas relative to conventional resources in the United States will be described, and this will be compared with the economics of gas elsewhere in the world. In discussing the economics of shale gas, the very important issue of intra and inter-play well-to-well performance variability will be highlighted. The presentation will also describe some of the major environmental concerns that surround that shale gas production. The issue of water intensity in hydraulic fracturing operations will be examined, as will the concerns regarding surface and subsurface water contamination. The debate regarding the GHG footprint of hydraulic fracturing operations will be described and an assessment of ``potential'' and ``actual'' fugitive methane emissions from hydraulic fracturing

A centrifuge is claimed for the separation of gaseous mixtures with a rotor inside a housing, comprising a hollow, cylindrical or nearly cylindrical rotorpart also called a separating drum, in which drum a gaseous component may condense as a liquid. This liquid is admitted thereafter through openings in the drum to the space between drum and housing. In this space are formed a sequence of narrow openings, so called restrictors in which the liquid is brought to expansion, returning to gas form. These restrictors act also as bearings for the drum. The gaseous component that does not liquefy in the drum is drawn off.

The Energy Information Administration's (EIA) Liquid Fuels and NaturalGas in the Americas report, published today, is a Congressionally-requested study examining the energy trends and developments in the Americas over the past decade. The report focuses on liquid fuels and natural gas—particularly reserves and resources, production, consumption, trade, and investment—given their scale and significance to the region.

EIA has responded to a December 4, 2014 Nature article on projections of shale gas production made by EIA and by the Bureau of Economic Geology of the University of Texas at Austin (BEG/UT) with a letter to the editors of Nature. BEG/UT has also responded to the article in their own letter to the editor.

The latest report on undiscovered conventional oil and gas resources outside the United States estimates that there are more undiscovered and technically recoverable naturalgas and naturalgas liquids (NGLs) but less oil than had previously been thought. The 18 April report, issued by the U.S. Geological Survey (USGS) as part of its World Petroleum Resource Project, estimates that there are 5606 trillion cubic feet of naturalgas, compared with 4669 trillion cubic feet in the previous assessment, in 2000, and 167 billion barrels of NGLs compared with an earlier 207 billion barrels. The assessment also estimates that there are 565 billion barrels of oil compared with an earlier 649 billion. About 75% of those resources outside the United States are located in four regions: South America and the Caribbean, sub-Saharan Africa, the Middle East and North Africa, and the Arctic provinces portion of North America, according to the new assessment.

Emissions factors for pipeline naturalgas leaks are in need of refinement. In addition to limitations from the small sample sizes of leaks that were initially used to develop emissions factors, a further limitation to emissions factors is lack of knowledge of characteristic statistical distributions of pipeline leak rates. For example, leaks were implicitly assumed to be normally distributed so that an average leak rate was used for pipelines of a given construction. Our naturalgas leak data from Boston, USA, in which we found over 3,000 naturalgas leaks, indicates that leaks rates are highly skewed, with relatively few leaks likely contributing disproportionately to the total. The long-tailed distribution of gas leak rates is mirrored by a similarly skewed distribution of surface methane concentrations in air. These data suggest that emissions factors should be based on correctly specified statistical distributions, and that fixing relatively few large leaks first may provide the most environmental benefit per cost.

Low quality naturalgas processing with the integrated CFZ/CNG Claus process is feasible for low quality naturalgas containing 10% or more of CO{sub 2}, and any amount of H{sub 2}S. The CNG Claus process requires a minimum CO{sub 2} partial pressure in the feed gas of about 100 psia (15% CO{sub 2} for a 700 psia feed gas) and also can handle any amount of H{sub 2}S. The process is well suited for handling a variety of trace contaminants usually associated with low quality naturalgas and Claus sulfur recovery. The integrated process can produce high pressure carbon dioxide at purities required by end use markets, including food grade CO{sub 2}. The ability to economically co-produce high pressure CO{sub 2} as a commodity with significant revenue potential frees process economic viability from total reliance on pipeline gas, and extends the range of process applicability to low quality gases with relatively low methane content. Gases with high acid gas content and high CO{sub 2} to H{sub 2}S ratios can be economically processed by the CFZ/CNG Claus and CNG Claus processes. The large energy requirements for regeneration make chemical solvent processing prohibitive. The cost of Selexol physical solvent processing of the LaBarge gas is significantly greater than the CNG/CNG Claus and CNG Claus processes.

This study is a detailed comparative analysis of liquefied naturalgas (LNG) and compressed naturalgas (CNG). The study provides data on two alternative fuels used by transit agencies in Texas. First, we examine the `state-of-the- art` in alternative fuels to established a framework for the study. Efforts were made to examine selected characteristics of two types of naturalgas demonstrations in terms of the following properties: energy source characteristics, vehicle performance and emissions, operations, maintenance, reliability, safety costs, and fuel availability. Where feasible, two alternative fuels were compared with conventional gasoline and diesel fuel. Environmental considerations relative to fuel distribution and use are analyzed, with a focus on examining flammability an other safety-related issues. The objectives of the study included: (1) assess the state-of-the-art and document relevant findings pertaining to alternative fuels; (2) analyze and synthesize existing databases on two naturalgas alternatives: liquefied naturalgas (LNG) and compressed naturalgas (CNG): and (3) compare two alterative fuels used by transit properties in Texas, and address selected aspects of alternative fuels such as energy source characteristics, vehicle performance and emissions, safety, costs, maintenance and operations, environmental and related issues.

Naturalgas use in Egypt, although still in its infancy, has risen rapidly during the past few years and even larger increases are expected. The extent to which naturalgas usage can improve Egypt's foreign-exchange position by allowing greater exports of oil is herein examined. A linear-programming model is used to identify shadow prices for naturalgas production and transportation costs and for the world market costs of other fuels. The model thus determines the minimum foreign exchange costs needed to operate the Egyptian naturalgas industry and other Egyptian sectors that have the option of using naturalgas (the fertilizer, electric power generation, Helwan iron and steel, cement, and residential and commercial sectors). Only existing production facilities are considered. Results show that the most important application for naturalgas is in the manufacture of cement; use in iron and steel production is indicated when electricity demand is low or coal prices are high. A 17-item bibliography (1972-1982) is appended.

LDEF (Prelaunch), AO175 : Evaluation of Long-Duration Exposure to the Natural Space Environment on Graphite-Polyimide and Graphite-Epoxy Mechanical Properties, Tray A07 The Graphite-Polyimide and Graphite-Epoxy Mechanical Properties experiment fills two (2) three (3) inch deep peripheral trays, A01 and A07. The experiment in the A07 experiment tray, shown in this photograph, consist of three (3) Graphite-Polyimide laminate panels and associated mounting hardware. Each panel occupies one third (1/3) of the LDEF experiment tray; a PMR-15 precured graphite-polyimide panel (T40T30060-009) in the right one third section, a F-178/T300 cocured graphite-polyimide panel (T40T30060-005) in the center one third section and a F-178/T300 precured graphite-polyimide panel (T40T30060-001) is in the left one third section of the tray. The panels are held in place with aluminum strips and non-magnetic stainless steel fasteners. The aluminum strips are covered with a dull gold coating over most of the exposed surface. The coating has been scraped from the aluminum mounting strip near the upper left tray corner. The mounting system, designed to allow for differential thermal expansion, minimizes the risk of inducing high stresses into the test panels. PMR-15 Graphite-Polyimide Panel (precured) - The PMR-15 graphite-polyimide laminated panel (T40T30060-009) is a uniform dark brown with a yellow identification number. The panel has several off-white marks in the lower right corner and light grayish-brown discolorations can be seen behind the identification number and behind the off-white marks. F-178/T300 Graphite-Polyimide Panel (cocured) - The F178/T300 graphite-polyimide laminated panel (T40T30060-005) is also a dark brown with a yellow identification number and small offwhite marks in the lower right corner. F-178/300 Graphite-Polyimide Panel (precured) - The F178/300 graphite-polyimide laminated panel (T40T30060-001) is a dark brown color with a yellow identification number and

LDEF (Flight), AO175 : Evaluation of Long-Duration Exposure to the Natural Space Environment on Graphite-Polyimide and Graphite-Epoxy Mechanical Properties, Tray A07 The flight photograph was taken while the LDEF was attached to the Orbiter's RMS arm prior to berthing in the Orbiter's cargo bay. The paint dots on the tray clampblocks have changed little from the orginal white color. The dots along the lower tray flange seem to have a faint light brown tint. The dull gold coating observed on the aluminum mounting strips in the prelaunch photograph has turned to a medium brown. The areas where the coating was scraped or abraided away appears as a metallic surface. PMR-15 Graphite-Polyimide Panel (precured) - The PMR-15 graphite-polyimide laminated panel (T40T30060-009) appears to have changed from the prelaunch brown color to a light gray. A geometric pattern, probably the results of the laminating process, is visible on the panel surface. Fine horizontal lines, cracks and/or crazing, can be seen over the geometrical pattern. The yellow colored identification numbers seem to be a little darker in the flight photograph but the white marking in the upper left corner do not appear to have changed. Scratch marks / abrasions on the lower left edge of panel were on prelaunch photographs. F-178/T300 Graphite-Polyimide Panel (cocured) - The 178/T300 graphite-polyimide panel (T40T30060-005) seems to have changed from the pre-launch dark brown to a light gray color. The yellow identification numbers seem darker in the flight photograph while the white marking in the upper left corner appear brighter. There appears to be fine horizontal lines, cracks and/or crazing, on the panel surface. F178/T300 Graphite-Polyimide Panel (precured) - The 178/T300 graphite-polyimide laminated panel (T40T30060-001) seems to have changed from the prelaunch dark brown color with a lighter brown area along its vertical center, extending from top to bottom, to a uniform light gray color. The yellow

The Office of NaturalGas and Petroleum Import and Export Activities prepares quarterly reports summarizing the data provided by companies authorized to import or export naturalgas. Companies are required, as a condition of their authorizations, to file quarterly reports. This report is for the first quarter of 1998 (January through March). Attachment A shows the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the five most recent reporting quarters. Attachment B shows volumes and prices of gas purchased by long-term importers and exporters during the past 12 months. Attachment C shows volume and price information pertaining to gas imported on a short-term or spot market basis. Attachment D shows the gas exported on a short-term or spot market basis to Canada and Mexico.

The Office of NaturalGas and Petroleum Import and Export Activities prepares quarterly reports summarizing the data provided by companies authorized to import or export naturalgas. Attachment A shows the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the five most recent reporting quarters. Attachment B shows volumes and prices of gas purchased by long-term importers and exporters during the past 12 months. Attachment C shows volume and price information pertaining to gas imported on a short-term or spot market basis. Attachment D shows the gas exported on a short-term or spot market basis to Canada and Mexico. 14 figs., 9 tabs.

The Office of NaturalGas and Petroleum Import and Export Activities prepares quarterly reports summarizing the data provided by companies authorized to import or export naturalgas. Companies are required, as a condition of their authorizations, to file quarterly reports. This report is for the third quarter of 1998 (July--September). Attachment A shows the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the five most recent calendar quarters. Attachment B shows volumes and prices of gas purchased by long-term importers and exporters during the past 12 months. Attachment C shows volume and price information pertaining to gas imported on a short-term or spot market basis. Attachment D shows the gas exported on a short-term or spot market basis to Canada and Mexico.

The Office of NaturalGas and Petroleum Import and Export Activities prepared quarterly reports summarizing the data provided by companies authorized to import or export naturalgas. Companies are required, as a condition of their authorizations, to file quarterly reports. This report is for the second quarter of 1998 (April through June). Attachment A shows the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the five most recent reporting quarters. Attachment B shows volumes and prices of gas purchased by long-term importers and exporters during the past 12 months. Attachment C shows volume and price information pertaining to gas imported on a short-term or spot market basis. Attachment D shows the gas exported on a short-term or spot market basis to Canada and Mexico.

The Office of NaturalGas and Petroleum Import and Export Activities prepares quarterly reports summarizing the data provided by companies authorized to import or export naturalgas. Companies are required, as a condition of their authorizations, to file quarterly reports. This report is for the fourth quarter of 1998 (October through December). Attachment A shows the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the five most recent reporting quarters. Attachment B shows volumes and prices of gas purchased by long-term importers and exporters during the past 12 months. Attachment C shows volume and price information pertaining to gas imported on a short-term or spot market basis. Attachment D shows the gas exported on a short-term or spot market basis to Canada and Mexico.

This quarterly report, prepared by The Office of NaturalGas and Petroleum Import and Export Activities, summarizes the data provided by companies authorized to import or export naturalgas. Numerical data are presented in four attachments, each of which is comprised of a series of tables. Attachment A shows the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the five most recent calendar quarters. Volumes and prices of gas purchased by long-term importers and exporters during the past year are given in Attachment B. Attachment C shows volume and price information pertaining to gas imported on a short-term or spot market basis. Attachment D lists gas exported on a short-term or spot market basis to Canada and Mexico. Highlights of the report are very briefly summarized.

The genetic types, source precursors and filling pattern of naturalgas in the Upper Carboniferous Taiyuan Formation, Lower Permian Shanxi Formation and Lower Shihezi Formation gas reservoirs of Daniudi gas field were investigated using chemical composition as well as carbon and hydrogen isotopic compositions. Geochemical analysis of natural gases in 25 representative wells shows that naturalgas in the Daniudi gas field is composed predominantly of hydrocarbons with a dryness coefficient of 0.884-0.978. The carbon isotopic values of ethane and propane are higher than -28‰ and -25‰, respectively, and the hydrogen isotopic values of methane are lower than -180‰, indicating that naturalgas in the Daniudi field is a typical coal-type gas, derived mainly from humic organic matter in the transitional facies of the Carboniferous-Permian age. Hydrogen isotopic values of CH4 and H2 display a good positive correlation, suggesting that both were controlled by thermal maturity. When the mixing of ethane generated from mudstone and coal with the same kerogen type and similar thermal maturity occurred, the carbon isotopic values of ethane barely reflect the thermal maturity. Although the fractionation of hydrogen isotopes of ethane is significantly higher than that of carbon, hydrogen isotopic values of ethane in naturalgas reservoirs evidently are not related to thermal maturity. The Daniudi naturalgas reservoirs represent both self-sourced and near-source accumulations. The naturalgas accumulations in the Late Triassic-Early Jurassic periods are mainly of the self-sourced type, while accumulations in the Late Jurassic-Early Cretaceous period comprise both self-sourced and near-source patterns, and the naturalgas reservoirs formed after the Late Cretaceous period are mainly of the near-source type.

This Project Final Report serves to document the project structure and technical results achieved during the 3-year project titled Advanced Autothermal Reformer for US Dept of Energy Office of Industrial Technology. The project was initiated in December 2001 and was completed March 2005. It was a joint effort between Sandia National Laboratories (Livermore, CA), Kellogg Brown & Root LLC (KBR) (Houston, TX) and Süd-Chemie (Louisville, KY). The purpose of the project was to develop an experimental capability that could be used to examine the propensity for soot production in an Autothermal Reformer (ATR) during the production of hydrogen-carbon monoxide synthesis gas intended for Gas-to-Liquids (GTL) applications including ammonia, methanol, and higher hydrocarbons. The project consisted of an initial phase that was focused on developing a laboratory-scale ATR capable of reproducing conditions very similar to a plant scale unit. Due to budget constraints this effort was stopped at the advanced design stages, yielding a careful and detailed design for such a system including ATR vessel design, design of ancillary feed and let down units as well as a PI&D for laboratory installation. The experimental effort was then focused on a series of measurements to evaluate rich, high-pressure burner behavior at pressures as high as 500 psi. The soot formation measurements were based on laser attenuation at a view port downstream of the burner. The results of these experiments and accompanying calculations show that soot formation is primarily dependent on oxidation stoichiometry. However, steam to carbon ratio was found to impact soot production as well as burner stability. The data also showed that raising the operating pressure while holding mass flow rates constant results in considerable soot formation at desirable feed ratios. Elementary reaction modeling designed to illuminate the role of CO2 in the burner feed showed that the conditions in the burner allow for the direct

Distributed energy is an approach for meeting energy needs that has several advantages. Distributed energy improves energy security during natural disasters or terrorist actions, improves transmission grid reliability by reducing grid load, and enhances power quality through voltage support and reactive power. In addition, distributed energy can be efficient since transmission losses are minimized. One prime mover for distributed energy is the naturalgas reciprocating engine generator set. Naturalgas reciprocating engines are flexible and scalable solutions for many distributed energy needs. The engines can be run continuously or occasionally as peak demand requires, and their operation and maintenance is straightforward. Furthermore, system efficiencies can be maximized when naturalgas reciprocating engines are combined with thermal energy recovery for cooling, heating, and power applications. Expansion of naturalgas reciprocating engines for distributed energy is dependent on several factors, but two prominent factors are efficiency and emissions. Efficiencies must be high enough to enable low operating costs, and emissions must be low enough to permit significant operation hours, especially in non-attainment areas where emissions are stringently regulated. To address these issues the U.S. Department of Energy and the California Energy Commission launched research and development programs called Advanced Reciprocating Engine Systems (ARES) and Advanced Reciprocating Internal Combustion Engines (ARICE), respectively. Fuel efficiency and low emissions are two primary goals of these programs. The work presented here was funded by the ARES program and, thus, addresses the ARES 2010 goals of 50% thermal efficiency (fuel efficiency) and <0.1 g/bhp-hr emissions of oxides of nitrogen (NOx). A summary of the goals for the ARES program is given in Table 1-1. ARICE 2007 goals are 45% thermal efficiency and <0.015 g/bhp-hr NOx. Several approaches for improving the

We investigate multipartite entanglement in a noninteracting fermion gas, as a function of fermion separation, starting from the many particle fermion density matrix. We prove that all multiparticle entanglement can be built only out of two-fermion entanglement. Although from the Pauli exclusion principle we would always expect entanglement to decrease with fermion distance, we surprisingly find the opposite effect for certain fermion configurations. The von Neumann entropy is found to be proportional to the volume for a large number of particles even when they are arbitrarily close to each other. We will illustrate our results using different configurations of two, three, and four fermions at zero temperature although all our results can be applied to any temperature and any number of particles. PMID:16090728

Large-scale nucleation of gas hydrate takes place when hydrate-forming gas and seawater are brought together under suitable pressure-temperature conditions or where dissolved hydrate-forming gas in saturated or near-saturated seawater is chilled or brought to higher pressures. Profuse formation of hydrate shells on gas bubbles and nucleation of at least five different forms of gas hydrate have been achieved in fresh natural seawater. Growth of masses of solid gas hydrate takes place when hydrate-forming gas reactant dissolved in seawater is brought into the vicinity of the hydrate. The gas concentration of the enriched water in the vicinity of hydrate is higher than the hydrate equilibrium gas concentration. Hydrate growth under these conditions is accelerated due to the chemical potential difference between the enriched water and the hydrate crystals, which induces mass flux of dissolved hydrate forming gas into new hydrate crystals. As long as water enriched in the hydrate-forming gas is circulated into the vicinity of the hydrate, growth proceeds into the water space. Experimental approaches for growth of examples of solid masses of hydrate are presented. Results of these experiments provide an insight into the growth of gas hydrate under natural conditions where interstitial water in marine sediments is captured by burial from open seawater, and where solid gas hydrate forms on the seafloor. By using fresh natural seawater, which is a chemically and materially complex fluid, our experiments in pressurized, refrigerated reactors should closely track the growth history of solid hydrate in the natural environment. In our model for hydrate growth in sediments, nearly complete pore fill by diagenetic hydrate can best be accomplished by nucleation of hydrate at a point source within the pore water or at a particular point on sediment particulate, with growth outward into the water space that is refreshed with ground water having high concentrations of hydrate

This analysis investigates strategies for Fort Drum to acquire a reliable naturalgas supply while reducing its gas supply costs. The purpose of this study is to recommend an optimal supply mix based on the life-cycle costs of each strategy analyzed. In particular, this study is intended to provide initial guidance as to whether or not the building and operating of a propane-air mixing station is a feasible alternative to the current gas acquisition strategy. The analysis proceeded by defining the components of supply (gas purchase, gas transport, supplemental fuel supply); identifying alternative options for each supply component; constructing gas supply strategies from different combinations of the options available for each supply component and calculating the life-cycle costs of each supply strategy under a set of different scenarios reflecting the uncertainty of future events.

Low levels of natural radioactivity in the ground produce radon-222 and its decay products which can be entrained with gas streams and become distributed with gas supplies to commercial and domestic users. Levels of radon in blended gas received by most users are comparable with the levels that are present naturally in buildings as a result of ingress from the ground and this is further diluted during the combustion process. For typical rates of gas usage with an average radon level of about 200 Bq x m(-3), the estimated dose from the use of naturalgas is estimated at 4 microSv, less than 1% of the dose from radon exposure at the average level in UK homes. Commercial users may receive somewhat higher doses, and the estimate for a critical group is a few tens of microsievert. The total radon emission to the environment is estimated at about 10(13) Bq x y(-1) which represents less than 10(-4) of the natural emission rate from the ground. There is some variability of radon levels in gas from different sources and it would be prudent to keep this source of exposure under review. A standard sampling and measurement protocol has been developed in conjunction with a technical group representing the industry. PMID:11843341

Gas clathrate hydrates were first identified in 1810 by Sir Humphrey Davy. However, it is believed that other scientists, including Priestley, may have observed their existence before this date. They are solid crystalline inclusion compounds consisting of polyhedral water cavities which enclathrate small gas molecules. Naturalgas hydrates are important industrially because the occurrence of these solids in subsea gas pipelines presents high economic loss and ecological risks, as well as potential safety hazards to exploration and transmission personnel. On the other hand, they also have technological importance in separation processes, fuel transportation and storage. They are also a potential fuel resource because natural deposits of predominantly methane hydrate are found in permafrost and continental margins. To progress with understanding and tackling some of the technological challenges relating to naturalgas hydrate formation, inhibition and decomposition one needs to develop a fundamental understanding of the molecular mechanisms involved in these processes. This fundamental understanding is also important to the broader field of inclusion chemistry. The present article focuses on the application of a range of physico-chemical techniques and approaches for gaining a fundamental understanding of naturalgas hydrate formation, decomposition and inhibition. This article is complementary to other reviews in this field, which have focused more on the applied, engineering and technological aspects of clathrate hydrates. PMID:12122641

The total of probable, possible, and speculative resources of undiscovered recoverable naturalgas from conventional reservoirs in Pennsylvania is estimated to be approximately 8.5 tcf. The total undiscovered and potentially recoverable gas resource in unconventional reservoirs may be about 11.1 tcf. Conventional naturalgas resources were estimated in five general stratigraphic packages, using differing approaches made necessary by the variable character and density of the data available, conditioned by time considerations. These packages and their total of probable, possible, and speculative resources are: Mississippian and Upper Devonian sands, 3.6 tcf; Onondaga/Oriskany and related reservoirs, 1.5 tcf; Lower Silurian Medina Sandstones, 1.8 tcf; Silurian Tuscarora and Cambrian-Ordovician formations, 0.7 tcf; Eastern Overthrust belt, 0.9 tcf. Unconventional resources are: naturalgas in coal beds, 2.7 tcf; Devonian shale gas, 8.4 tcf. General subdivisions of the estimated conventional resources are 31% probable, 40% possible, and 29% speculative. In contrast, subdivisions of estimated unconventional resources are 11, 24, and 65%, respectively. Short-term projections demonstrate that production of naturalgas in Pennsylvania can be doubled without stress and maintained at that level for several years. Much beyond 10 years, however, projections become speculations.

Under a contract from DOE`s National Renewable Energy Laboratory (NREL) and support from Brooklyn Union Gas Company (BUG), Northern Illinois Gas Co., the Institute of Gas Technology (IGT) evaluated four state-of-the-art, electronic, closed-loop naturalgas vehicle (NGV) conversion systems. The systems included an Impco electronic closed-loop system, Mogas electronic closed-loop system, Stewart and Stevenson`s GFI system, and an Automotive NaturalGas Inc. (ANGI) Level 1 electronic closed-loop conversion system. Conversion system evaluation included emission testing per 40 CFR Part 86, and driveability. All testing was performed with a 1993 Chevy Lumina equipped with a 3.1 liter MPFI V6 engine. Each system was emission tested using three different certified compositions of naturalgas, representing the 10th, mean and 90th percentile gas compositions distributed in the United States. Emission testing on indolene was performed prior to conversion kit testing to establish a base emission value. Indolene testing was also performed at the end of the project when the vehicle was converted to its OEM configuration to ensure that the vehicle`s emissions were not altered during testing. The results of these tests will be presented.

Consistent comparisons of the amount of land required for different electricity generation technologies are challenging because land use associated with fossil fuel acquisition and delivery has not been well characterized or empirically grounded. This research focuses on improving estimates of the life cycle land use of naturalgas-fired electricity (m2/MWh generated) through the novel combination of inventories of naturalgas-related infrastructure, satellite imagery analysis and gas production estimates. We focus on seven counties that represent 98% of the total gas production in the Barnett Shale (Texas), evaluating over 500 sites across five life cycle stages (gas production, gathering, processing, transmission, and power generation as well as produced water disposal). We find that a large fraction of total life cycle land use is related to gathering (midstream) infrastructure, particularly pipelines; access roads related to all stages also contribute a large life cycle share. Results were sensitive to several inputs, including well lifetime, pipeline right of way, number of wells per site, variability of heat rate for electricity generation, and facility lifetime. Through this work, we have demonstrated a novel, highly-resolved and empirical method for estimating life cycle land use from naturalgas infrastructure in an important production region. When replicated for other gas production regions and other fuels, the results can enable more empirically-grounded and robust comparisons of the land footprint of alternative energy choices.

According to the author, the bubble is just about history. The gas supply base shrunk by 6 Tcf to 148 Tcf by year-end 1988 and is expected to fall by another 7 Tcf this year. In 1989, annual deliverability will drop below 19 Tcf or an average of about 1,600 Bcf, which is too close for comfort to the maximum monthly production rate that regularly occurs in winter months. Monthly peaks during severe weather have pushed occasional monthly production to well over 1,700 Bcf. Given any kind of long-lasting cold snap affecting most of the Northeast and Midwest, such peaks could stress the system to the point of random deliverability shortfall this winter. And certainly, if not this winter, shortfall will come earlier and more frequently during the 1989-90 winter season as the deliverability slide goes on. A shortfall will likely be pipeline and/or market area specific, and will result from deliverability as well as operating problems. There are an increasing number of fields in which maximum rates cannot be sustained for any length of time.

Shale deposits exist in many parts of the world and contain relatively large amounts of naturalgas and oil. Recent technological developments in the process of horizontal hydraulic fracturing (hydrofracturing or fracking) have suddenly made it economically feasible to extract naturalgas from shale. While naturalgas is a much cleaner burning fuel than coal, there are a number of significant threats to human health from the extraction process as currently practiced. There are immediate threats to health resulting from air pollution from volatile organic compounds, which contain carcinogens such as benzene and ethyl-benzene, and which have adverse neurologic and respiratory effects. Hydrogen sulfide, a component of naturalgas, is a potent neuro- and respiratory toxin. In addition, levels of formaldehyde are elevated around fracking sites due to truck traffic and conversion of methane to formaldehyde by sunlight. There are major concerns about water contamination because the chemicals used can get into both ground and surface water. Much of the produced water (up to 40% of what is injected) comes back out of the gas well with significant radioactivity because radium in subsurface rock is relatively water soluble. There are significant long-term threats beyond cancer, including exacerbation of climate change due to the release of methane into the atmosphere, and increased earthquake activity due to disruption of subsurface tectonic plates. While fracking for naturalgas has significant economic benefits, and while naturalgas is theoretically a better fossil fuel as compared to coal and oil, current fracking practices pose significant adverse health effects to workers and near-by residents. The health of the public should not be compromized simply for the economic benefits to the industry. PMID:26943595

The introduction of naturalgas to the transportation energy sector offers the possibility of displacing imported oil with an indigenous fuel. The barrier to the acceptance of naturalgas vehicles (NGV) is the limited driving range due to the technical difficulties of on-board storage of a gaseous fuel. In spite of this barrier, compressed naturalgas (CNG) vehicles are today being successfully introduced into the market place. The purpose of this work is to demonstrate an adsorbent naturalgas (ANG) storage system as a viable alternative to CNG storage. It can be argued that low pressure ANG has reached near parity with CNG, since the storage capacity of CNG (2400 psi) is rated at 190 V/V, while low pressure ANG (500 psi) has reached storage capacities of 180 V/V in the laboratory. A program, which extends laboratory results to a full-scale vehicle test, is necessary before ANG technology will receive widespread acceptance. The objective of this program is to field test a 150 V/V ANG vehicle in FY 1994. As a start towards this goal, carbon adsorbents have been screened by Brookhaven for their potential use in a naturalgas storage system. This paper reports on one such carbon, trade name Maxsorb, manufactured by Kansai Coke under an Amoco license.

Naturalgas is a mixture of low molecular weight hydrocarbon gases that can be generated from either fossil or anthropogenic resources. Although naturalgas is used as a transportation fuel, constraints in storage, relatively low energy content (MJ/L), and delivery have limited widespread adoption. Advanced utilization of naturalgas has been explored for biofuel production by microorganisms. In recent years, the aerobic bioconversion of naturalgas (or primarily the methane content of naturalgas) into liquid fuels (Bio-GTL) by biocatalysts (methanotrophs) has gained increasing attention as a promising alternative for drop-in biofuel production. Methanotrophic bacteria are capable of converting methane into microbial lipids, which can in turn be converted into renewable diesel via a hydrotreating process. In this paper, biodiversity, catalytic properties and key enzymes and pathways of these microbes are summarized. Bioprocess technologies are discussed based upon existing literature, including cultivation conditions, fermentation modes, bioreactor design, and lipid extraction and upgrading. This review also outlines the potential of Bio-GTL using methane as an alternative carbon source as well as the major challenges and future research needs of microbial lipid accumulation derived from methane, key performance index, and techno-economic analysis. An analysis of raw material costs suggests that methane-derived diesel fuel has the potential to be competitive with petroleum-derived diesel. (C) 2014 The Authors. Published by Elsevier Inc.

Naturalgas is a mixture of low molecular weight hydrocarbon gases that can be generated from either fossil or anthropogenic resources. Although naturalgas is used as a transportation fuel, constraints in storage, relatively low energy content (MJ/L), and delivery have limited widespread adoption. Advanced utilization of naturalgas has been explored for biofuel production by microorganisms. In recent years, the aerobic bioconversion of naturalgas (or primarily the methane content of naturalgas) into liquid fuels (Bio-GTL) by biocatalysts (methanotrophs) has gained increasing attention as a promising alternative for drop-in biofuel production. Moreover, methanotrophic bacteria are capable of converting methane into microbial lipids, which can in turn be converted into renewable diesel via a hydrotreating process. In this paper, biodiversity, catalytic properties and key enzymes and pathways of these microbes are summarized. Bioprocess technologies are discussed based upon existing literature, including cultivation conditions, fermentation modes, bioreactor design, and lipid extraction and upgrading. Our review also outlines the potential of Bio-GTL using methane as an alternative carbon source as well as the major challenges and future research needs of microbial lipid accumulation derived from methane, key performance index, and techno-economic analysis. An analysis of raw material costs suggests that methane-derived diesel fuel has the potential to be competitive with petroleum-derived diesel.

The objective was to determine the technical and financial feasibility of liquefying remote reserves of naturalgas and transporting the liquefied product to users. The proposed methodology included efforts to (1) identify any prohibitive or limiting laws and/or regulations; (2) identify sufficient unutilized reserves in remote areas to justify further investigation; (3) identify existing portable liquefaction equipment (or an interested manufacturer that could supply the needed equipment) to obtain cost and performance data; (4) determine site preparation, supply and production costs for use in assessing economic feasibility; and (5) identify potential users. The conclusion is that the liquefaction of naturalgas in remote areas of Appalachia is not economically feasible as long as an adequate and reliable supply of pipeline gas is perceived to be available for the forseable future and the price per Btu of pipeline gas remains so far below other fuels. 3 tables.

The detection of naturalgas pipeline leak becomes a significant issue for body security, environmental protection and security of state property. However, the leak detection is difficult, because of the pipeline's covering many areas, operating conditions and complicated environment. A mobile sensor for remote detection of naturalgas leakage based on scanning wavelength differential absorption spectroscopy (SWDAS) is introduced. The improved soft threshold wavelet denoising was proposed by analyzing the characteristics of reflection spectrum. And the results showed that the signal to noise ratio (SNR) was increased three times. When light intensity is 530 nA, the minimum remote sensitivity will be 80 ppm x m. A widely used SWDAS can make quantitative remote sensing of naturalgas leak and locate the leak source precisely in a faster, safer and more intelligent way. PMID:22512213

Algeria is increasing its capacity to export naturalgas in order to reinforce its strong position in the growing international market. The country's reserves are estimated at more than 3.6 trillion cu m. Algerian energy and development policy is based on a rational exploitation of this resource. A liquefield naturalgas (LNG) pioneer, Algeria has one of the world's most important LNG production capacities. With a location encouraging export to nearby countries, Algeria has an important place in the world naturalgas market and an exclusive role within its trading region. The effort will especially focus on southern Europe. The paper discusses Algeria's growing role in international markets, as well as local markets.

A fuel delivery system includes a fuel tank configured to receive liquid naturalgas. A first conduit extends from a vapor holding portion of the fuel tank to an economizer valve. A second conduit extends from a liquid holding portion of the fuel tank to the economizer valve. Fluid coupled to the economizer valve is a vaporizer which is heated by coolant from the engine and is positioned below the fuel tank. The economizer valve selectively withdraws either liquid naturalgas or vaporized naturalgas from the fuel tank depending on the pressure within the vapor holding portion of the fuel tank. A delivery conduit extends from the vaporizer to the engine. A return conduit having a check valve formed therein extends from the delivery conduit to the vapor holding portion of the fuel tank for pressurizing the fuel tank.

Background Unconventional naturalgas development has expanded rapidly. In Pennsylvania the number of producing wells increased from zero in 2005 to 3689 in 2013. To our knowledge, no prior publications have focused on unconventional naturalgas development and birth outcomes. Methods We performed a retrospective cohort study using electronic health record data on 9384 mothers linked to 10946 neonates in the Geisinger Health System from January 2009-January 2013. We estimated cumulative exposure to unconventional naturalgas development activity with an inverse-distance squared model that incorporated distance to the mother’s home; dates and durations of well pad development, drilling, and hydraulic fracturing; and production volume during the pregnancy. We used multilevel linear and logistic regression models to examine associations between activity index quartile and term birth weight, preterm birth, low 5 minute Apgar score and small size for gestational age, while controlling for potential confounding variables. Results In adjusted models, there was an association between unconventional naturalgas development activity and preterm birth that increased across quartiles, with a fourth quartile odds ratio of 1.4 (95% CI: 1.0-1.9). There were no associations of activity with Apgar score, small for gestational age, or term birth weight (after adjustment for year). In a post-hoc analysis, there was an association with physician-recorded high-risk pregnancy identified from the problem list (fourth vs. first quartile, 1.3 [95% CI: 1.1-1.7]). Conclusion Prenatal residential exposure to unconventional naturalgas development activity was associated with two pregnancy outcomes, adding to evidence that unconventional naturalgas development may impact health. PMID:26426945

This quarter`s feature report focuses on naturalgas exports to Mexico. OFP invites ideas from the public on future topics dealing with North American naturalgas import/export trade. Such suggestions should be left on OFP`s electronic bulletin board. NaturalGas exports to Mexico continued to grow and reached an historic high for the month of June (7.8 Bcf). Two new long-term contracts were activated; Pennsylvania Gas & Water Company began importing 14.7 MMcf per day from TransCanada PipeLines Ltd., and Renaissance Energy (U.S.) Inc. began importing 2.8 MMcf per day from Renaissance Energy Ltd. for resale to Delmarva Power & Light Company. Algerian LNG imports remained stagnant with only one tanker being imported by Pan National Gas Sales, Inc. (Pan National). During the first six months of 1995, data indicates gas imports increased by about 10 percent over the 1994 level (1,418 vs. 1,285 Bcf), with Canadian imports increasing by 14 percent and Algerian imports decreasing by 81 percent. During the same time period, exports increased by 18 percent (83 vs. 70.1 Bcf).

A debate has raged in the past couple of years as to whether naturalgas is better or worse overall than coal and oil from a global warming perspective. The back-and-forth findings have been due to the timelines taken into consideration, the details of naturalgas extraction, and the electricity-generating efficiency of various fuels. An analysis by Cathles, which focuses exclusively on potential warming and ignores secondary considerations, such as economic, political, or other environmental concerns, finds that naturalgas is better for electricity generation than coal and oil under all realistic circumstances. To come to this conclusion, the author considered three different future fuel consumption scenarios: (1) a business-as-usual case, which sees energy generation capacity continue at its current pace with its current energy mix until the middle of the century, at which point the implementation of low-carbon energy sources dominates and fossil fuel-derived energy production declines; (2) a gas substitution scenario, where naturalgas replaces all coal power production and any new oil-powered facilities, with the same midcentury shift; and (3) a low-carbon scenario, where all electricity generation is immediately and aggressively switched to non-fossil fuel sources such as solar, wind, and nuclear.

While exploring ways of producing better fuels for propulsion of a spacecraft on the Mars sample return mission, a researcher at Johnson Space Center (JSC) devised a way of blending fuel by combining methane or naturalgas with a second fuel to produce a fuel that can be maintained in liquid form at ambient temperature and under moderate pressure. The use of such a blended fuel would be a departure for both spacecraft engines and terrestrial internal combustion engines. For spacecraft, it would enable reduction of weights on long flights. For the automotive industry on Earth, such a fuel could be easily distributed and could be a less expensive, more efficient, and cleaner-burning alternative to conventional fossil fuels. The concept of blending fuels is not new: for example, the production of gasoline includes the addition of liquid octane enhancers. For the future, it has been commonly suggested to substitute methane or compressed naturalgas for octane-enhanced gasoline as a fuel for internal-combustion engines. Unfortunately, methane or naturalgas must be stored either as a compressed gas (if kept at ambient temperature) or as a cryogenic liquid. The ranges of automobiles would be reduced from their present values because of limitations on the capacities for storage of these fuels. Moreover, technical challenges are posed by the need to develop equipment to handle these fuels and, especially, to fill tanks acceptably rapidly. The JSC alternative to provide a blended fuel that can be maintained in liquid form at moderate pressure at ambient temperature has not been previously tried. A blended automotive fuel according to this approach would be made by dissolving naturalgas in gasoline. The autogenous pressure of this fuel would eliminate the need for a vehicle fuel pump, but a pressure and/or flow regulator would be needed to moderate the effects of temperature and to respond to changing engine power demands. Because the fuel would flash as it entered engine

Hydraulic fracturing and horizontal drilling techniques have been extensively used to extract unconventional naturalgas in the northeast of the United States. Over the past few years, the presence of contaminants in shallow groundwater near drilling sites has created higher awareness of drinking water quality. One key question has been recently raised about the origin and pathways of the contaminants, especially naturalgas found in groundwater in neighboring areas of gas drilling sites in northeast Pennsylvania. Methane (CH4), which is the main component of naturalgas, is not currently classified as a health hazard when dissolved in drinking water. Yet, it is a threat for explosion and fire hazards. In the Bradford, Susquehanna, Tioga, and Wyoming counties located in northeast Pennsylvania, dissolved methane concentration was measured to be 19.2 mg/l. Maximum concentration was recorded up to 64 mg/l when a warning level of concentration of naturalgas in groundwater is only 10 mg/l. Recent studies have been investigating the origin of naturalgas found in water wells in these counties based on the isotopic composition of methane, ethane and dissolved inorganic carbon. While Breen et al. (2007) and Osborn et al. (2010 and 2011) claim that the isotopic analysis of methane confirms the thermogenic origin of methane in groundwater in Susquehanna and Wyoming counties, Molofsky et al. (2011) claim that the naturalgas origin in the groundwater is not related to fracking activities in the Marcellus Shale but to a geologic origin instead. To better understand the origin of dissolved methane, an integral computer model will be implemented. The model will analyze the potential migration of naturalgas to shallow groundwater by using available data. Potential scenarios will include outgassing from wells casing and preferential flow through deep fractures. Currently, the lack of a proper model prevents the prediction and explanation of several of the existing questions

U.S. crude oil proved reserves increased in 2014 for the sixth year in a row with a net addition of 3.4 billion barrels of proved oil reserves (a 9% increase), according to U.S. Crude Oil and NaturalGas Proved Reserves, 2014, released today by the U.S. Energy Information Administration (EIA). U.S. naturalgas proved reserves increased 10% in 2014, raising the U.S. total to a record 388.8 trillion cubic feet.

A water model has been used to determine the positions of separate inlet ports for a naturalgas, stratified charge rotary engine. The flow inside the combustion chamber (mainly during the induction period) has been registered by a film camera. From these tests the best locations of the inlet ports have been obtained, a prototype of this engine has been built by Audi NSU and tested in the laboratories of the university of Gent. The results of these tests, for different stratification configurations, are given. These results are comparable with the best results obtained by Audi NSU for a homogeneous naturalgas rotary engine.

In this era of energy consciousness, NaturalGas is destined to play an important role in the economic life of India. The luxury of flaring into atmosphere is over. Rather stocks are being assessed and capital investments are planned for the optimum development and utilisation of gas. In this paper, authors have attempted to tie up various data on different aspects of gas business such as supply, source, production, utilisation pattern and its share in energy and economy. The optimal utilisation plan as discussed here could be of some value to the planners.

A model of odorizing a naturalgas is built on the basis of the system of motion of viscous, compressible, heatconducting, two-component medium with account for the odorant diffusion. Calculations of convective and diffusional mixing, in a channel, of a gaseous methane main flow interacting with its side jets containing an odorizing gas has been performed. The regimes of flow at different gas velocities in the main and side channels are considered, and the process of the equalization of the odorant concentration by convective and diffusional mechanisms are considered.

The Knowledge Management Database (KMD) Portal provides four options for searching the documents and data that NETL-managed oil and gas research has produced over the years for DOE’s Office of Fossil Energy. Information includes R&D carried out under both historical and ongoing DOE oil and gas research and development (R&D). The Document Repository, the CD/DVD Library, the Project Summaries from 1990 to the present, and the Oil and NaturalGas Program Reference Shelf provide a wide range of flexibility and coverage.

The Marcellus Shale is a sedimentary rock formation deposited over 350 million years ago in a shallow inland sea located in the eastern United States where the present-day Appalachian Mountains now stand (de Witt and others, 1993). This shale contains significant quantities of naturalgas. New developments in drilling technology, along with higher wellhead prices, have made the Marcellus Shale an important naturalgas resource. The Marcellus Shale extends from southern New York across Pennsylvania, and into western Maryland, West Virginia, and eastern Ohio (fig. 1). The production of commercial quantities of gas from this shale requires large volumes of water to drill and hydraulically fracture the rock. This water must be recovered from the well and disposed of before the gas can flow. Concerns about the availability of water supplies needed for gas production, and questions about wastewater disposal have been raised by water-resource agencies and citizens throughout the Marcellus Shale gas development region. This Fact Sheet explains the basics of Marcellus Shale gas production, with the intent of helping the reader better understand the framework of the water-resource questions and concerns.

Naturalgas hydrates are generally associated with pockmarks or mud volcanoes on margins. They occurred both in deep sedimentary structures, and sometimes as outcrops on the seafloor. The gas hydrates studied here were collected from gravity sediment cores and occur as small fragments and massive crystal aggregates, mostly disseminated irregularly in the sediment. In most cases, they escape in the overlying deep seawater creating CH4-rich plumes which extend 100-150 m above the seafloor. These plumes are also enriched in particles, manganese, iron related to discharges of high turbid fluids issued from sediments and in all cases methane is rejected from sediment as free gas or as a consequence of the decomposition of gas hydrates. Specific equipments are necessary for collecting, and storing these gas hydrates in good conditions to avoid decomposition. The crystalline structure of solid gas hydrates is studied by Raman Spectrometry and Synchrotron techniques and show mainly methane gas hydrate of cubic Structure I. Analyses of hydrate water show variations (depletions or enrichments) of mineral elements compared to ambient deep seawater. Gas analysis shows that CH4 is the major component but CO2 and heavier gases (C2H4, C2H6, H2S) are also present as traces. In addition, many families of organic compounds detected by chromatography-mass spectrometry are present as traces. In most cases, the carbon and hydrogen isotopic data indicate a primarily microbial origin for the CH4 which is generated through bacterial CO2 reduction. All these chemical data contribute to understand the origin, formation and stability of gas hydrates trapped in sediments on oceanic margins. Specimens of naturalgas hydrates recently collected on the African and Norvegian margins will be discussed.

This program is focusing on the development of mixed ionic and electronic conducting materials based on the brown millerite structure for use in catalytic membrane reactors (CMRs). These CMRs are being evaluated for promoting the spontaneous and highly selective oxidative reforming of carbon dioxide / naturalgas mixtures to synthesis gas.

Ya13-1 is one of the largest gas field ever found in China in recent years. Studying on the genetic type of naturalgas in the field is one of the key factors to determine the regional hydrocarbon potential--Qiongdongnan Basin and Yinggerhaii Basin, northwest part of South China Sea. Series of geochemical methods have been undertook including the analysis of the chemical composition of the naturalgas and their isotopic ratio discussed in this paper. Other related studied including geological settings, gas-source correlations, geochemistry of the condensates and extractable compounds of source rocks, and thermal simulation and evaluation of the marine shales provides further informations. It is noticeable that the higher content of mercury (44000 ng/cubic meter) and aromatics such as benzene and toluene may be related to the joint of condensates, which derived from coal-bearing Oligocene shales in the adjacent Qingdingnan Basin. Studies show that the naturalgas in Ya13-1 gas field belong to high to post mature non-associated gas derived in marine source rocks, and mainly come from Oligocene to Pliocene marine shales in Yinggerhai Basin. This is quite different with the former studies, which believe the gas derived from Oligocene coal-bearing strata of Yacheng formation, Qiongdongnan Basin. The new results of the studies make sure further a pretty good potential of gas resources in the northwest part ofSouth China Sea.

Increased use of naturalgas has been promoted as a means of decarbonizing the US power sector, because of superior generator efficiency and lower CO2 emissions per unit of electricity than coal. We model the effect of different gas supplies on the US power sector and greenhouse gas (GHG) emissions. Across a range of climate policies, we find that more abundant naturalgas decreases use of both coal and renewable energy technologies in the future. Without a climate policy, overall energy use also increases as the gas supply increases. With reduced deployment of lower-carbon renewable energies and increased electricity consumption, the effect of higher gas supplies on GHG emissions is small: cumulative emissions 2013-2055 in our high gas supply scenario are 2% less than in our low gas supply scenario, when there are no new climate policies and a methane leakage rate of 1.5% is assumed. Assuming leakage rates of 0 or 3% does not substantially alter this finding. In our results, only climate policies bring about a significant reduction in future CO2 emissions within the US electricity sector. Our results suggest that without strong limits on GHG emissions or policies that explicitly encourage renewable energy, more abundant naturalgas may actually slow the process of decarbonization, primarily by delaying deployment of renewable energy technologies.

In the second phase of this project, the newly developed membrane module for naturalgas dehydration was tested and evaluated in a pilot plant located at a commercial naturalgas treatment site. This phase was undertaken jointly with UOP LLC, our commercialization partner. The field test demonstrated that a commercial-size membrane module for naturalgas dehydration was successfully manufactured. The membrane module operated reliably over 1000 psi differential pressure across the membrane in the field test. The effects of feed gas pressure, permeate gas pressure, feed flow rate, purge ratio (flow rate ratio of permeate outlet to feed), and feed gas dew point on the membrane module performance were determined and found to meet the design expectations. Although water vapor permeance was lower than expected, substantial naturalgas dehydration was demonstrated with low purge ratio. For example, dew point was suppressed by as much as 30 F with only about 2 {approx} 3% purge ratio. However the bore side pressure drops were significantly higher than the projected value from the fluid dynamic calculation. It is likely that not all the fibers were open in either the sweep or the permeate tube sheet end. This could help to explain the relatively low water vapor permeances that were measured in the field. An economic evaluation of the membrane process and the traditional Triethylene Glycol (TEG) process to dehydrate naturalgas was performed and the economics of the two processes were compared. Two sets of membrane module performance properties were used in the economic analysis of the membrane process. One was from the results of this field test and the other from the results of the previous small-scale test with a medium pressure membrane variant conducted at 750 psig. The membrane process was competitive with the TEG process for the naturalgas feed flow rate below 10 MMSCFD for the membrane with previously measured water vapor permeance. The membrane process was

... jurisdictional naturalgas facilities other than liquefied naturalgas facilities caused by a hurricane... reason other than hurricane, earthquake or other natural disaster or terrorist activity, the natural...

This report describes a research program that was conducted to define naturalgas contaminant levels necessary to insure that internal corrosion of compressed naturalgas (CNG) cylinders does not constitute a hazard over the lifetimes of the cylinders. A literature search was performed and companies in the naturalgas transmission and distribution industries were contacted: to identify and determine the composition ranges of contaminants in natural gases; and to obtain information regarding corrosion damage of CNG cylinders and cylinder materials. Corrosion and stress corrosion cracking (SCC) tests were performed on the cylinder materials most widely used in CNG cylinders in the United States (4130X and 15B30 steels and 6061-T6 aluminum alloy). Tests were conducted in: natural gases from several producing wells and from an interstate pipeline; and in aqueous solutions saturated with varying concentrations of naturalgas contaminants. Also, metallurgical analyses of nine (eight steel and one aluminum), used CNG cylinders were performed. Limiting concentrations of hydrogen sulfide (H{sub 2}S), carbon dioxide (CO{sub 2}), and other CNG contaminants necessary to prevent internal corrosion of CNG fuel and storage cylinders were defined. This knowledge will minimize potential hazards of using CNG as a vehicle fuel. It should also lead to reduced costs of CNG use, since it has been shown that reduction of contaminants to the very low levels currently specified by the U.S. Department of Transportation (DOT) and the Canadian Transport Commission (CTC) is not necessary. A gas-quality standard based on program results is recommended. The National Fire Protection Association (NFPA) has adopted the recommended gas-quality standard.

The purpose of this study is to examine recent trends and prospects for the future of the U.S. naturalgas market. Naturalgas prices rose dramatically in 2000 and remained high through the first part of 2001, raising concerns about the future of naturalgas prices and potential for naturalgas to fuel the growth of the U.S. economy.

The United States has 11 distinct naturalgas pipeline corridors: five originate in the Southwest, four deliver naturalgas from Canada, and two extend from the Rocky Mountain region. This study assesses the potential to deliver hydrogen through the existing naturalgas pipeline network as a hydrogen and naturalgas mixture to defray the cost of building dedicated hydrogen pipelines.

... NaturalGas Act. 284.3 Section 284.3 Conservation of Power and Water Resources FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURALGAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURALGAS UNDER THE NATURALGAS POLICY ACT OF 1978...

... 30 Mineral Resources 2 2014-07-01 2014-07-01 false How do suspension volumes apply to naturalgas... General § 203.73 How do suspension volumes apply to naturalgas? You must measure naturalgas production under the royalty-suspension volume as follows: 5.62 thousand cubic feet of naturalgas, measured...

... 30 Mineral Resources 2 2010-07-01 2010-07-01 false How do I measure naturalgas production on my... do I measure naturalgas production on my eligible lease? You must measure naturalgas production on... naturalgas, measured according to part 250, subpart L of this title, equals one barrel of oil...

... NaturalGas Act. 284.3 Section 284.3 Conservation of Power and Water Resources FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURALGAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURALGAS UNDER THE NATURALGAS POLICY ACT OF 1978...

... NaturalGas Act. 284.3 Section 284.3 Conservation of Power and Water Resources FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURALGAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURALGAS UNDER THE NATURALGAS POLICY ACT OF 1978...

... 30 Mineral Resources 2 2012-07-01 2012-07-01 false How do suspension volumes apply to naturalgas... General § 203.73 How do suspension volumes apply to naturalgas? You must measure naturalgas production under the royalty-suspension volume as follows: 5.62 thousand cubic feet of naturalgas, measured...

... NaturalGas Act. 284.3 Section 284.3 Conservation of Power and Water Resources FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURALGAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURALGAS UNDER THE NATURALGAS POLICY ACT OF 1978...

... NaturalGas Act. 284.3 Section 284.3 Conservation of Power and Water Resources FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURALGAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURALGAS UNDER THE NATURALGAS POLICY ACT OF 1978...

... 30 Mineral Resources 2 2013-07-01 2013-07-01 false How do suspension volumes apply to naturalgas... General § 203.73 How do suspension volumes apply to naturalgas? You must measure naturalgas production under the royalty-suspension volume as follows: 5.62 thousand cubic feet of naturalgas, measured...

... Energy Regulatory Commission NaturalGas Pipeline Company of America LLC; Notice of Application August 12, 2010. Take notice that on July 30, 2010, NaturalGas Pipeline Company of America LLC (NaturalGas...), and sections 157.7 and 157.18 of the Commission's regulations under the NaturalGas Act (NGA)...

This comment examines the Federal Energy Regulatory Commission's (FERC) naturalgas regulatory authority and its policies and procedures for the interpretation of naturalgas sales contracts and settlement agreements. It concludes that the FERC has prescribed a workable method for the post NaturalGas Policy Act (NGPA) interpretation of area rate clauses. The procedures and guidelines established in the Independent Oil and Gas Association, with the exception of the exclusion of evidence of settlement negotiations, promise to be fair to all parties in litigation over the meaning of area rate clauses. The FERC recognized that the limitations of drafting placed on the naturalgas industry by the NGA and FERC regulations may have inhibited the free expression of intent in the words of the contract, thus requiring the use of extrinsic evidence. The FERC's formulation of objective textual standards for the interpretation of area rate clauses, when evidence of the parties' intent is absent or inconclusive, provides administrative law judges with clear guidelines and generally allows contracts to be interpreted in accordance with the parties' intent. The author feels the FERC's exclusion of evidence of settlement negotiations is misguided, however, and should be reconsidered. The negotiation of contracts in the context of settlement proceedings should not be a bar to the admissibility of evidence necessary to interpret an ambiguous contract provision. The FERC's position is not supportable in law or policy and should therefore be reversed.

Economic studies on simulated gas hydrate reservoirs have been compiled to estimate the price of naturalgas that may lead to economically viable production from the most promising gas hydrate accumulations. As a first estimate, $CDN2005 12/Mscf is the lowest gas price that would allow economically viable production from gas hydrates in the absence of associated free gas, while an underlying gas deposit will reduce the viability price estimate to $CDN2005 7.50/Mscf. Results from a recent analysis of the simulated production of naturalgas from marine hydrate deposits are also considered in this report; on an IROR basis, it is $US2008 3.50-4.00/Mscf more expensive to produce marine hydrates than conventional marine gas assuming the existence of sufficiently large marine hydrate accumulations. While these prices represent the best available estimates, the economic evaluation of a specific project is highly dependent on the producibility of the target zone, the amount of gas in place, the associated geologic and depositional environment, existing pipeline infrastructure, and local tariffs and taxes. ?? 2009 Elsevier B.V.

This application concerns systems and methods for compressing naturalgas with an internal combustion engine. In a representative embodiment, a system for compressing a gas comprises a reciprocating internal combustion engine including at least one piston-cylinder assembly comprising a piston configured to travel in a cylinder and to compress gas in the cylinder in multiple compression stages. The system can further comprise a first pressure tank in fluid communication with the piston-cylinder assembly to receive compressed gas from the piston-cylinder assembly until the first pressure tank reaches a predetermined pressure, and a second pressure tank in fluid communication with the piston-cylinder assembly and the first pressure tank. The second pressure tank can be configured to receive compressed gas from the piston-cylinder assembly until the second pressure tank reaches a predetermined pressure. When the first and second pressure tanks have reached the predetermined pressures, the first pressure tank can be configured to supply gas to the piston-cylinder assembly, and the piston can be configured to compress the gas supplied by the first pressure tank such that the compressed gas flows into the second pressure tank.

My dissertation concentrates on several aspects of supply chain management and economic valuation of real options in the naturalgas and liquefied naturalgas (LNG) industry, including gas pipeline transportations, ocean LNG shipping logistics, and downstream storage. Chapter 1 briefly introduces the naturalgas and LNG industries, and the topics studied in this thesis. Chapter 2 studies how to value U.S. naturalgas pipeline network transport contracts as real options. It is common for naturalgas shippers to value and manage contracts by simple adaptations of financial spread option formulas that do not fully account for the implications of the capacity limits and the network structure that distinguish these contracts. In contrast, we show that these operational features can be fully captured and integrated with financial considerations in a fairly easy and managerially significant manner by a model that combines linear programming and simulation. We derive pathwise estimators for the so called deltas and structurally characterize them. We interpret them in a novel fashion as discounted expectations, under a specific weighing distribution, of the amounts of naturalgas to be procured/marketed when optimally using pipeline capacity. Based on the actual prices of traded naturalgas futures and basis swaps, we show that an enhanced version of the common approach employed in practice can significantly underestimate the true value of naturalgas pipeline network capacity. Our model also exhibits promising financial (delta) hedging performance. Thus, this model emerges as an easy to use and useful tool that naturalgas shippers can employ to support their valuation and delta hedging decisions concerning naturalgas pipeline network transport capacity contracts. Moreover, the insights that follow from our data analysis have broader significance and implications in terms of the management of real options beyond our specific application. Motivated by current developments

Results of a Next Generation NaturalGas Vehicle engine research project: A Caterpillar C-12 naturalgas engine with Clean Air Power Dual-Fuel technology and exhaust gas recirculation demonstrated low NOx and PM emissions.

Naturally occurring gas hydrates have the potential to store enormous volumes of both gas and water in semi-solid form in ocean-bottom sediments and then to release that gas and water when the hydrate's equilibrium condition are disturbed. Therefore, hydrates provide a potential mechanism for transporting large volumes of sediments. Under the combined low bottom-water temperatures and moderate hydrostatic pressures that exist over most of the continental slopes and all of the continental rises and abyssal plains, hydrocarbon gases at or near saturation in the interstitial waters of the near-bottom sediments will form hydrates. The gas can either be autochthonous, microbially produced gas, or allochthonous, catagenic gas from deeper sediments. Equilibrium conditions that stabilize hydrated sediments may be disturbed, for example, by continued sedimentation or by lowering of sea level. In either case, some of the solid gas-water matrix decomposes. Released gas and water volume exceeds the volume occupied by the hydrate, so the internal pressure rises - drastically if large volumes of hydrate are decomposed. Part of the once rigid sediment is converted to a gas- and water-rich, relatively low density mud. When the internal pressure, due to the presence of the compressed gas or to buoyancy, is sufficiently high, the overlying sediment may be lifted and/or breached, and the less dense, gas-cut mud may break through. Such hydrate-related phenomena can cause mud diapirs, mud volcanos, mud slides, or turbidite flows, depending on sediment configuration and bottom topography. 4 figures.

Rolls-Royce Fuel Cell Systems (US) Inc. (RRFCS) has developed a system that produces synthesis gas from air and naturalgas. A near-term application being considered for this technology is synthesis gas injection into reciprocating engines for reducing NO{sub x} emissions. A proof of concept study using bottled synthesis gas and a two-stroke reciprocating engine showed that injecting small amounts of high-flammable content synthesis gas significantly improved combustion stability and enabled leaner engine operation resulting in over 44% reduction in NO{sub x} emissions. The actual NO{sub x} reduction that could be achieved in the field is expected to be engine specific, and in many cases may be even greater. RRFCS demonstrated that its synthesis gas generator could produce synthesis gas with the flammable content that was successfully used in the engine testing. An economic analysis of the synthesis gas approach estimates that its initial capital cost and yearly operating cost are less than half that of a competing NO{sub x} reduction technology, Selective Catalytic Reduction. The next step in developing the technology is an integrated test of the synthesis gas generator with an engine to obtain reliability data for system components and to confirm operating cost. RRFCS is actively pursuing opportunities to perform the integrated test. A successful integrated test would demonstrate the technology as a low-cost option to reduce NO{sub x} emissions from approximately 6,000 existing two-stroke, naturalgas-fired reciprocating engines used on naturalgas pipelines in North America. NO{sub x} emissions reduction made possible at a reasonable price by this synthesis gas technology, if implemented on 25% of these engines, would be on the order of 25,000 tons/year.

Rolls-Royce Fuel Cell Systems (US) Inc. (RRFCS) has developed a system that produces synthesis gas from air and naturalgas. A near-term application being considered for this technology is synthesis gas injection into reciprocating engines for reducing NOx emissions. A proof of concept study using bottled synthesis gas and a two-stroke reciprocating engine showed that injecting small amounts of highflammables content synthesis gas significantly improved combustion stability and enabled leaner engine operation resulting in over 44% reduction in NOx emissions. The actual NOx reduction that could be achieved in the field is expected to be engine specific, and in many cases may be even greater. RRFCS demonstrated that its synthesis gas generator could produce synthesis gas with the flammables content that was successfully used in the engine testing. An economic analysis of the synthesis gas approach estimates that its initial capital cost and yearly operating cost are less than half that of a competing NOx reduction technology, Selective Catalytic Reduction. The next step in developing the technology is an integrated test of the synthesis gas generator with an engine to obtain reliability data for system components and to confirm operating cost. RRFCS is actively pursuing opportunities to perform the integrated test. A successful integrated test would demonstrate the technology as a low-cost option to reduce NOx emissions from approximately 6,000 existing two-stroke, naturalgas-fired reciprocating engines used on naturalgas pipelines in North America. NOx emissions reduction made possible at a reasonable price by this synthesis gas technology, if implemented on 25% of these engines, would be on the order of 25,000 tons/year.

The commercialization of gaseous hydrogen fueled vehicles requires both the development of hydrogen fueled vehicles and the establishment of a hydrogen fueling infrastructure. These requirements create a classic chicken and egg scenario in that manufacturers will not build and consumers will not buy vehicles without an adequate refueling infrastructure and potential refueling station operators will not invest the needed capital without an adequate market to serve. One solution to this dilemma is to create a bridging strategy whereby hydrogen is introduced gradually via another carrier. The only contending alternative fuel that can act as a bridge to hydrogen fueled vehicles is naturalgas. To explore this possibility, IGT is conducting emission tests on its dedicated naturalgas vehicle (NGV) test platform to determine what, if any, effects small quantities of hydrogen have on emissions and performance. Furthermore, IGT is actively developing an adsorbent based low-pressure naturalgas storage system for NGV applications. This system has also shown promise as a storage media for hydrogen. A discussion of our research results in this area will be presented. Finally, a review of IGT's testing facility will be presented to indicate our capabilities in conducted naturalgas/hydrogen vehicle (NGHV) research. 3 refs., 10 figs.

This Supplement to the Energy Information Administration's Short-Term Energy Outlook analyzes current naturalgas production, pipeline and storage infrastructure in the Rocky Mountains, as well as prospective pipeline projects in these states. The influence of these factors on regional prices and price volatility is examined.

Metal-organic frameworks have received significant attention as a new class of adsorbents for naturalgas storage; however, inconsistencies in reporting high-pressure adsorption data and a lack of comparative studies have made it challenging to evaluate both new and existing materials. Here, we briefly discuss high-pressure adsorption measurements and review efforts to develop metal-organic frameworks with high methane storage capacities. To illustrate the most important properties for evaluating adsorbents for naturalgas storage and for designing a next generation of improved materials, six metal-organic frameworks and an activated carbon, with a range of surface areas, pore structures, and surface chemistries representative of the most promising adsorbents for methane storage, are evaluated in detail. High-pressure methane adsorption isotherms are used to compare gravimetric and volumetric capacities, isosteric heats of adsorption, and usable storage capacities. Additionally, the relative importance of increasing volumetric capacity, rather than gravimetric capacity, for extending the driving range of naturalgas vehicles is highlighted. Other important systems-level factors, such as thermal management, mechanical properties, and the effects of impurities, are also considered, and potential materials synthesis contributions to improving performance in a complete adsorbed naturalgas system are discussed.

This career awareness booklet provides information and activities to help youth prepare for career and explore jobs in the naturalgas industry. Students are exposed to career planning ideas and activities; they learn about a wide variety of industry jobs, what workers say about their jobs, and how the industry operates. Five sections are…

This report explores the significant and changing role of storage in the industry by examining the value of naturalgas storage; short-term relationships between prices, storage levels, and weather; and some longer term impacts of the Federal Energy Regulatory Commission's (FERC) Order 636.

The second quarter 1997 Quarterly Report of NaturalGas Imports and Exports featured a Quarterly Focus report on cross-border naturalgas trade between the United States and Mexico. This Quarterly Focus article is a follow-up to the 1997 report. This report revisits and updates the status of some of the pipeline projects discussed in 1997, and examines a number of other planned cross-border pipeline facilities which were proposed subsequent to our 1997 report. A few of the existing and proposed pipelines are bidirectional and thus have the capability of serving either Mexico, or the United States, depending on market conditions and gas supply availability. These new projects, if completed, would greatly enhance the pipeline infrastructure on the U.S.-Mexico border and would increase gas pipeline throughput capacity for cross-border trade by more than 1 billion cubic feet (Bcf) per day. The Quarterly Focus is comprised of five sections. Section I includes the introduction as well as a brief historic overview of U.S./Mexican naturalgas trade; a discussion of Mexico's energy regulatory structure; and a review of trade agreements and a 1992 legislative change which allows for her cross-border gas trade in North America. Section II looks at initiatives that have been taken by the Mexican Government since 1995to open its energy markets to greater competition and privatization. Section III reviews Mexican gas demand forecasts and looks at future opportunities for U.S. gas producers to supplement Mexico's indigenous supplies in order to meet the anticipated rapid growth in demand. Section IV examines the U.S.-Mexico naturalgas trade in recent years. It also looks specifically at monthly import and export volumes and prices and identifies short-term trends in this trade. Finally, Section V reviews the existing and planned cross-border gas pipeline infrastructure. The section also specifically describes six planned pipelines intended to expand this pipeline network and

A natural-gas-fed spark-ignition engine, operating under lean conditions, is used for the study of the organic acids exhaust emissions. These pollutants are collected by passing a sample of exhaust gas into deionised water. The final solution is directly analysed by HPLC/UV at 204 nm. Only formic acid is emitted in detectable concentration under the experimental conditions used. Its concentration decreases with the three engine operating parameters studied: spark advance, volumetric efficiency and fuel/air equivalence ratio. Exhaust formic acid concentration is also linked with exhaust oxygen concentration and exhaust temperature. A comparison with other engines (SI engines fed with gasoline and compression ignition engines) from bibliographic data proves that natural-gas-fed engines emit less organic acids than the other two types of engines.

An airborne laser remote sensing technology is proposed to detect naturalgas pipeline leakage in helicopter which carrying a detector, and the detector can detect a high spatial resolution of trace of methane on the ground. The principle of the airborne laser remote sensing system is based on tunable diode laser absorption spectroscopy (TDLAS). The system consists of an optical unit containing the laser, camera, helicopter mount, electronic unit with DGPS antenna, a notebook computer and a pilot monitor. And the system is mounted on a helicopter. The principle and the architecture of the airborne laser remote sensing system are presented. Field test experiments are carried out on West-East NaturalGas Pipeline of China, and the results show that airborne detection method is suitable for detecting gas leak of pipeline on plain, desert, hills but unfit for the area with large altitude diversification.

Updated data showing capacity, demand, and production of naturalgas and comparisons of actual versus reported deliverability explore the reasons why producing rates during periods when demand cannot be fully met do not represent true delivery capacity, and contrasts the opinions of experts on the size and durability of US reserves. The author concludes that adequate reserves and deliverability of reasonably priced naturalgas will be available for the rest of the century and beyond that for high priority users. However, he argues against relying on overstated gas delivery capacity, if it is actually overstated, to meet future energy needs on the grounds that we could experience the same unplanned for shortages as well experienced in the early 1970s with oil. 5 figures.

Human conflict, geopolitical crises, terrorist attacks, and natural disasters can turn large parts of energy distribution networks offline. Europe's current gas supply network is largely dependent on deliveries from Russia and North Africa, creating vulnerabilities to social and political instabilities. During crises, less delivery may mean greater congestion, as the pipeline network is used in ways it has not been designed for. Given the importance of the security of naturalgas supply, we develop a model to handle network congestion on various geographical scales. We offer a resilient response strategy to energy shortages and quantify its effectiveness for a variety of relevant scenarios. In essence, Europe's gas supply can be made robust even to major supply disruptions, if a fair distribution strategy is applied. PMID:24621655

Methods of indirectly measuring the nitrogen concentration in a naturalgas by heating the gas. In two embodiments, the heating energy is correlated to the speed of sound in the gas, the diluent concentrations in the gas, and constant values, resulting in a model equation. Regression analysis is used to calculate the constant values, which can then be substituted into the model equation. If the diluent concentrations other than nitrogen (typically carbon dioxide) are known, the model equation can be solved for the nitrogen concentration.

Inhalation of essential oils can be used in aromatherapy due to their activating or relaxing effects. The study of these effects requires behavioral measurements on living subjects, by varying the nature and also the quantity of the volatile substances to be present in the atmosphere. So, to permit the evaluation of therapeutic effects of a variety of natural oils, we propose to develop an automatic diffusion/detection system capable to create an ambient air with low stabilized concentration of chosen oil. In this work, we discuss the performance of an array of eight gas sensors to discriminate low and constant concentrations of a chosen natural oil.

Major and minor components of naturalgas are routinely analyzed by gas chromatography (GC), using a thermal conductivity (TC). The best results obtained by these methods can report no better than 0.01 mole percent of each measured component. Even the extended method of analysis by flame ionization detector (FID) can only improve on the detection limit of hydrocarbons. The gas industry needs better information on all trace constituents of naturalgas, whether native or inadvertently added during gas processing that may adversely influence the operation of equipment or the safety of the consumer. The presence of arsenic and mercury in some gas deposits have now been documented in international literature as causing not only human toxicity but also damaging to the field equipment. Yet, no standard methods of sampling and analysis exist to provide this much needed information. In this paper the authors report the results of a three-year program to develop an extensive array of sampling and analysis methods for speciation and measurement of trace constituents of naturalgas. A cryogenic sampler operating at near 200 K ({minus}99 F) and at pipeline pressures up to 12.4 {times} 10{sup 6}Pa (1800 psig) has been developed to preconcentrate and recover all trace constituents with boiling points above butanes. Specific analytical methods have been developed for speciating and measurement of many trace components (corresponding to US EPA air toxics) by GC-AED and GC-MS, and for determining various target compounds by other techniques. Moisture, oxygen and sulfur contents are measured on site using dedicated field instruments. Arsenic, mercury and radon are sampled by specific solid sorbents for subsequent laboratory analysis.

Deliverability on the Interstate NaturalGas Pipeline System examines the capability of the national pipeline grid to transport naturalgas to various US markets. The report quantifies the capacity levels and utilization rates of major interstate pipeline companies in 1996 and the changes since 1990, as well as changes in markets and end-use consumption patterns. It also discusses the effects of proposed capacity expansions on capacity levels. The report consists of five chapters, several appendices, and a glossary. Chapter 1 discusses some of the operational and regulatory features of the US interstate pipeline system and how they affect overall system design, system utilization, and capacity expansions. Chapter 2 looks at how the exploration, development, and production of naturalgas within North America is linked to the national pipeline grid. Chapter 3 examines the capability of the interstate naturalgas pipeline network to link production areas to market areas, on the basis of capacity and usage levels along 10 corridors. The chapter also examines capacity expansions that have occurred since 1990 along each corridor and the potential impact of proposed new capacity. Chapter 4 discusses the last step in the transportation chain, that is, deliverability to the ultimate end user. Flow patterns into and out of each market region are discussed, as well as the movement of naturalgas between States in each region. Chapter 5 examines how shippers reserve interstate pipeline capacity in the current transportation marketplace and how pipeline companies are handling the secondary market for short-term unused capacity. Four appendices provide supporting data and additional detail on the methodology used to estimate capacity. 32 figs., 15 tabs.

The Office of Fuels Programs prepares quarterly reports summarizing the data provided by companies with authorizations to import or export naturalgas. Companies are required, as a condition of their authorizations, to file quarterly reports with the OFP. This report is for the third quarter of 1993 (July--September). Attachment A shows the percentage of takes to maximum firm contract levels and the weighted average per unit price for each of the long-term importers during the five most recent reporting quarters. Attachment B shows volumes and prices of gas purchased by long-term importers and exporters during the past twelve months (October 1992--September 1993). Attachment C shows volume and price information pertaining to gas imported on a short-term or spot market basis. Attachment D shows the gas exported on a short-term or spot market basis to Canada and Mexico.

The Epe cavern storage facility operated by Ruhrgas AG has developed into one of the largest gas cavern storage facilities in the world. Currently, there are 32 caverns and 18 more are planned in the future. Working gas volume will increase from approximately 1.5 {times} 10{sup 9} to 2 {times} 10{sup 9} m{sup 3}. The stratified salt deposit containing the caverns has a surface area of approximately 7 km{sup 2} and is 250 m thick at the edge and 400 m thick in the center. Caverns are leached by a company that uses the recovered brine in the chlorine industry. Cavern dimensions are determined before leaching. The behavior of each cavern, as well as the thermodynamic properties of naturalgas must be considered in cavern management. The full-length paper presents the components of a complex management system covering the design, construction, and operation of the Epe gas-storage caverns.

Naturalgas hydrates are solid, non-stoichiometric compounds of small gas molecules and water. They form when the constituents come into contact at low temperature and high pressure. The physical properties of these compounds, most notably that they are non-flowing crystalline solids that are denser than typical fluid hydrocarbons and that the gas molecules they contain are effectively compressed, give rise to numerous applications in the broad areas of energy and climate effects. In particular, they have an important bearing on flow assurance and safety issues in oil and gas pipelines, they offer a largely unexploited means of energy recovery and transportation, and they could play a significant role in past and future climate change.

Naturalgas hydrates are solid, non-stoichiometric compounds of small gas molecules and water. They form when the constituents come into contact at low temperature and high pressure. The physical properties of these compounds, most notably that they are non-flowing crystalline solids that are denser than typical fluid hydrocarbons and that the gas molecules they contain are effectively compressed, give rise to numerous applications in the broad areas of energy and climate effects. In particular, they have an important bearing on flow assurance and safety issues in oil and gas pipelines, they offer a largely unexploited means of energy recovery and transportation, and they could play a significant role in past and future climate change. PMID:14628065

Variability in soil mineralogy, texture, and pavement cover are involved in events leading to undetected gas leaks and subsequent explosions in Bowie, Md. and Washington, D.C. These geologic parameters are involved in selectively removing the gas odorant additive t-butyl merceptan as the gas came into contact with the soil near the pipeline breaks. This removal resulted in an accumulation of combustable naturalgas without detectable odor. Soil samples from drill holes and near surface sites were utilized to map soil type, texture, and mineralogy. Residual methane content of the samples was also measured. The data from two dissimilar sites indicates that finegrained soil enriched in montmorillonite preferentially removes the odorant.

The U.S. Geological Survey (USGS) has compiled a database consisting of three worksheets of central Appalachian basin naturalgas analyses and isotopic compositions from published and unpublished sources of 1,282 gas samples from Kentucky, Maryland, New York, Ohio, Pennsylvania, Tennessee, Virginia, and West Virginia. The database includes field and reservoir names, well and State identification number, selected geologic reservoir properties, and the composition of natural gases (methane; ethane; propane; butane, iso-butane [i-butane]; normal butane [n-butane]; iso-pentane [i-pentane]; normal pentane [n-pentane]; cyclohexane, and hexanes). In the first worksheet, location and American Petroleum Institute (API) numbers from public or published sources are provided for 1,231 of the 1,282 gas samples. A second worksheet of 186 gas samples was compiled from published sources and augmented with public location information and contains carbon, hydrogen, and nitrogen isotopic measurements of naturalgas. The third worksheet is a key for all abbreviations in the database. The database can be used to better constrain the stratigraphic distribution, composition, and origin of naturalgas in the central Appalachian basin.

Against the backdrop of increasingly volatile naturalgas prices, renewable energy resources, which by their nature are immune to naturalgas fuel price risk, provide a real economic benefit. Unlike many contracts for naturalgas-fired generation, renewable generation is typically sold under fixed-price contracts. Assuming that electricity consumers value long-term price stability, a utility or other retail electricity supplier that is looking to expand its resource portfolio (or a policymaker interested in evaluating different resource options) should therefore compare the cost of fixed-price renewable generation to the hedged or guaranteed cost of new naturalgas-fired generation, rather than to projected costs based on uncertain gas price forecasts. To do otherwise would be to compare apples to oranges: by their nature, renewable resources carry no naturalgas fuel price risk, and if the market values that attribute, then the most appropriate comparison is to the hedged cost of naturalgas-fired generation. Nonetheless, utilities and others often compare the costs of renewable to gas-fired generation using as their fuel price input long-term gas price forecasts that are inherently uncertain, rather than long-term naturalgas forward prices that can actually be locked in. This practice raises the critical question of how these two price streams compare. If they are similar, then one might conclude that forecast-based modeling and planning exercises are in fact approximating an apples-to-apples comparison, and no further consideration is necessary. If, however, naturalgas forward prices systematically differ from price forecasts, then the use of such forecasts in planning and modeling exercises will yield results that are biased in favor of either renewable (if forwards < forecasts) or naturalgas-fired generation (if forwards > forecasts). In this report we compare the cost of hedging naturalgas price risk through traditional gas-based hedging instruments (e

The anode exhaust gas from a fuel cell commonly has a fuel energy density between 15 and 25% that of the fuel supply, due to the incomplete oxidation of the input fuel. This exhaust gas is subsequently oxidized (catalytically or non-catalytically), and the resultant thermal energy is often used elsewhere in the fuel cell process. Alternatively, additional fuel can be added to this stream to enhance the oxidation of the stream, for improved thermal control of the power plant, or to adjust the temperature of the exhaust gas as may be required in other specialty co-generation applications. Regardless of the application, the cost of a fuel cell system can be reduced if the exhaust gas oxidation can be accomplished through direct gas phase oxidation, rather than the usual catalytic oxidation approach. Before gas phase oxidation can be relied upon however, combustor design requirements need to be understood. The work reported here examines the issue of fuel addition, primarily as related to molten-carbonate fuel cell technology. It is shown experimentally that without proper combustor design, the addition of naturalgas can readily quench the anode gas oxidation. The Chemkin software routines were used to resolve the mechanisms controlling the chemical quenching. It is found that addition of naturalgas to the anode exhaust increases the amount of CH3 radicals, which reduces the concentration of H and O radicals and results in decreased rates of overall fuel oxidation.

Naturalgas reservoirs of the mid-continent states of Oklahoma, Kansas, and Arkansas (northern part) have produced 103 trillion cubic ft (tcf) of naturalgas. Oklahoma has produced the most, having a cumulative production of 71 tcf. The major reservoirs (those that have produced more than 10 billion ft[sup 3]) have been identified and organized into 28 plays based on geologic age, lithology, and depositional environment. The Atlas of Major Midcontinent Gas Reservoirs, published in 1993, provides the documentation for these plays. This atlas was a collaborative effort of the Gas Research Institute; Bureau of Economic Geology. The University of Texas at Austin; Arkansas Geological Commission; Kansas Geological survey; and Oklahoma Geological Survey. Total cumulative production for 530 major reservoirs is 66 tcf associated and nonassociated gas. Oklahoma has the highest production with 39 tcf from 390 major reservoirs, followed by Kansas with 26 tcf from 105 major reservoirs. Most of the mid-continent production is from Pennsylvanian (46%) and Permian (41%) reservoirs; Mississippian reservoirs account for 10% production, and lower Paleozoic reservoirs, 3%. The largest play by far is the Wolfcampian Shallow Shelf Carbonate-Hugoton Embayment play with 25 tcf cumulative production, most of which is from the Hugoton and Panoma fields in Kansas and Guymon-Hugoton gas area in Oklahoma. A total of 53% of the mid-continent gas production is from dolostone and limestone reservoirs; 39% is from sandstone reservoirs. The remaining 8% is from chert conglomerate and granite-wash reservoirs. Geologically based plays established from the distribution of major gas reservoirs provide important support for the extension of productive trends, application of new resource technology to more efficient field development, and further exploration in the mid-continent region.